20-F

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 20-F

ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

for the fiscal year ended December 31, 2017

Commission File Number 0-99

PETRÓLEOS MEXICANOS

(Exact name of registrant as specified in its charter)

Mexican Petroleum	United Mexican States
(Translation of registrant’s name into English)	(Jurisdiction of incorporation or organization)

Avenida Marina Nacional No. 329

Colonia Verónica Anzures

11300 Ciudad de México, México

(Address of principal executive offices)

Jaime José del Río Castillo

(5255) 1944 9700

ri@pemex.com

Avenida Marina Nacional No. 329

Torre Ejecutiva, Piso 38 Colonia Verónica Anzures

11300 Ciudad de México, México

(Name, telephone, e-mail and/or facsimile number

and address of company contact person)

Securities registered or to be registered pursuant to Section 12(b) of the Act. None

Securities registered or to be registered pursuant to Section 12(g) of the Act. None

Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act.

Title of Each Class

3.500% Notes due 2018	Floating Rate Notes due 2018
3.125% Notes due 2019	5.500% Notes due 2019
8.00% Guaranteed Notes due 2019	3.500% Notes due 2020
6.000% Notes due 2020	6.375% Notes due 2021
5.50% Notes due 2021	4.875% Notes due 2022
5.375% Notes due 2022	Floating Rate Notes due 2022
8.625% Bonds due 2022	3.500% Notes due 2023
4.625% Notes due 2023	8.625% Guaranteed Bonds due 2023
4.875% Notes due 2024	4.250% Notes due 2025
4.500% Notes due 2026	6.875% Notes due 2026
9.50% Guaranteed Bonds due 2027	9.50% Global Guaranteed Bonds due 2027
6.500% Notes Due 2027	6.625% Guaranteed Bonds due 2035
6.625% Guaranteed Bonds due 2038	6.500% Bonds due 2041
5.50% Bonds due 2044	6.375% Bonds due 2045
5.625% Bonds due 2046	6.750% Bonds due 2047

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

Yes  ☐    No  ☒

If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934.

Yes  ☐    No  ☒

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes  ☒    No  ☐

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Yes  ☒    No  ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or an emerging growth company. See definitions of “large accelerated filer,” “accelerated filer,” and “emerging growth company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer	☐	Accelerated filer	☐
Non-accelerated filer	☒	Emerging growth company	☐

If an emerging growth company that prepares its financial statements in accordance with U.S. GAAP, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.  ☐

† The term “new or revised financial accounting standard” refers to any update issued by the Financial Accounting Standards Board to its Accounting Standards Codification after April 5, 2012.

Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing:

U.S. GAAP   ☐                IFRS as issued by the IASB  ☒                Other  ☐

If “Other” has been checked in response to the previous question, indicate by check mark which financial statement item the registrant has elected to follow.

Item 17  ☐                Item 18  ☐

If this is an annual report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes  ☐    No  ☒

TABLE OF CONTENTS

Item 1.	Identity of Directors, Senior Management and Advisers	5
Item 2.	Offer Statistics and Expected Timetable	5
Item 3.	Key Information	5
Item 4.	Information on the Company	19
Item 4A.	Unresolved Staff Comments	137
Item 5.	Operating and Financial Review and Prospects	137
Item 6.	Directors, Senior Management and Employees	177
Item 7.	Major Shareholders and Related Party Transactions	200
Item 8.	Financial Information	203
Item 9.	The Offer and Listing	208
Item 10.	Additional Information	208
Item 11.	Quantitative and Qualitative Disclosures About Market Risk	217
Item 12.	Description of Securities Other than Equity Securities	229
Item 13.	Defaults, Dividend Arrearages and Delinquencies	230
Item 14.	Material Modifications to the Rights of Security Holders and Use of Proceeds	230
Item 15.	Controls and Procedures	230
Item 16A.	Audit Committee Financial Expert	233
Item 16B.	Code of Ethics	233
Item 16C.	Principal Accountant Fees and Services	234
Item 16D.	Exemptions from the Listing Standards for Audit Committees	235
Item 16E.	Purchases of Equity Securities by the Issuer and Affiliated Purchasers	235
Item 16F.	Change in Registrant’s Certifying Accountant	235
Item 16G.	Corporate Governance	235
Item 16H.	Mine Safety Disclosure	235
Item 17.	Financial Statements	236
Item 18.	Financial Statements	236
Item 19.	Exhibits	236

i

Petróleos Mexicanos and its seven subsidiary entities, which we refer to as the subsidiary entities, Pemex Exploración y Producción (Pemex Exploration and Production), Pemex Transformación Industrial (Pemex Industrial Transformation), Pemex Perforación y Servicios (Pemex Drilling and Services), Pemex Logística (Pemex Logistics), Pemex Cogeneración y Servicios (Pemex Cogeneration and Services), Pemex Fertilizantes (Pemex Fertilizers) and Pemex Etileno (Pemex Ethylene), comprise the state oil and gas company of the United Mexican States, which we refer to as Mexico. Petróleos Mexicanos is a productive state-owned company of the Federal Government of Mexico, which we refer to as the Mexican Government, and each of the subsidiary entities is a productive state-owned subsidiary of Mexico. Each of Petróleos Mexicanos and the subsidiary entities is a legal entity empowered to own property and carry on business in its own name. In addition, a number of subsidiary companies that are defined in Note 1 and listed in Note 4 to our consolidated financial statements incorporated in Item 18, which we refer to as our subsidiary companies, are incorporated into the consolidated financial statements; these subsidiary companies are also identified with their corresponding ownership percentages in “––Consolidated Structure of PEMEX” on page 4. As further described under “Item 4—Information on the Company—History and Development—Corporate Reorganization,” the seven new subsidiary entities assumed, on or prior to, November 1, 2015, all of the rights and obligations of the prior subsidiary entities of Petróleos Mexicanos—Pemex-Exploración y Producción (Pemex-Exploration and Production), Pemex-Refinación (Pemex-Refining), Pemex-Gas y Petroquímica Básica (Pemex-Gas and Basic Petrochemicals) and Pemex-Petroquímica (Pemex-Petrochemicals). References to the subsidiary entities prior to this corporate reorganization refer to Pemex-Exploration and Production, Pemex-Refining, Pemex-Gas and Basic Petrochemicals and Pemex-Petrochemicals. Petróleos Mexicanos, the subsidiary entities and the subsidiary companies are collectively referred to as “PEMEX” or “we.” See “Item 4—Information on the Company—History and Development—Energy Reform” for more details.

References herein to “U.S. $,” “$,” “U.S. dollars” or “dollars” are to United States dollars. References herein to “pesos” or “Ps.” are to the legal currency of Mexico. References herein to “euros” or “€” are to the legal currency of the European Economic and Monetary Union. References herein to “pounds” or “£” are to the legal currency of the United Kingdom. References herein to “Swiss francs” are to the legal currency of the Swiss Confederation. References herein to “Japanese yen” or “¥” are to the legal currency of Japan. References herein to “Australian dollars” are to the legal currency of Australia. The term “billion” as used herein means one thousand million.

Our consolidated financial statements included in this annual report were prepared in accordance with International Financial Reporting Standards as issued by the International Accounting Standards Board. We refer in this report to “International Financial Reporting Standards as issued by the International Accounting Standards Board” as IFRS. In addition, these financial statements were audited in accordance with the International Standards on Auditing, as required by the Ley del Mercado de Valores (Securities Market Law) and the Disposiciones de carácter general aplicables a las emisoras de valores y a otros participantes del mercado de valores (General Provisions applicable to issuers of securities and other participants in the securities market) in each case, of Mexico, for purposes of filing with the Comisión Nacional Bancaria y de Valores (National Banking and Securities Commission, or the CNBV) and the Bolsa Mexicana de Valores, S.A.B. de C.V. (Mexican Stock Exchange), and in accordance with the standards of the Public Company Accounting Oversight Board (United States), or PCAOB, for purposes of filings with the U.S. Securities and Exchange Commission, or the SEC.

The regulations of the SEC do not require foreign private issuers that prepare their financial statements on the basis of IFRS to reconcile such financial statements to United States Generally Accepted Accounting Principles, which we refer to as U.S. GAAP. Accordingly, while we have in the past reconciled our consolidated financial statements prepared in accordance with Normas de Información Financiera Mexicanas (Mexican Financial Reporting Standards) to U.S. GAAP, those reconciliations are no longer presented in our filings with the SEC. We do, however, continue to provide the disclosure required under the U.S. Financial Accounting Standards Board Accounting Standards Codification (ASC) Topic 932 “Extractive Activities—Oil and Gas” (which we refer to as ASC Topic 932), as this is required regardless of the basis of accounting on which we prepare our financial statements.

We maintain our consolidated financial statements and accounting records in pesos. Unless otherwise indicated, we have translated all peso amounts to U.S. dollars in this Form 20-F, including all convenience translations of our consolidated financial statements included herein, at an exchange rate of Ps. 19.7867 = U.S. $1.00, which is the exchange rate that the Secretaría de Hacienda y Crédito Público (Ministry of Finance and Public Credit) instructed us to use on December 31, 2017. You should not construe these translations from pesos into dollars as actually representing such U.S. dollar amounts or meaning that you could convert such amounts into U.S. dollars at the rates indicated. Mexico has a free market for foreign exchange, and the Mexican Government allows the peso to float freely against the U.S. dollar. There can be no assurance that the Mexican Government will maintain its current policies with regard to the peso or that the peso will not depreciate or appreciate significantly in the future. Due to the volatility of the peso/U.S. dollar exchange rate, the exchange rate on any date subsequent to the date hereof could be materially different from the rate indicated above. See “Item 3—Key Information—Exchange Rates” for information regarding the rates of exchange between pesos and U.S. dollars.

PRESENTATION OF INFORMATION CONCERNING RESERVES

The proved hydrocarbon reserves included in this report for the year ended December 31, 2017 are those that we have the right to extract and sell based on assignments granted by the Mexican Government to us in August 2014 through the process commonly referred to as Round Zero and the assignments we have received in subsequent bidding rounds conducted by the Mexican Government. See “Item 4—Information on the Company—History and Development—Energy Reform” for a description of the Round Zero process.

The estimates of our proved reserves of crude oil and natural gas for the five years ended December 31, 2017 included in this report have been calculated according to the technical definitions required by the SEC. DeGolyer and MacNaughton, Netherland, Sewell International, S. de R.L. de C.V. (which we refer to as Netherland Sewell) and Ryder Scott Company, L.P. (which we refer to as Ryder Scott) conducted reserves audits of our estimates of our proved hydrocarbon reserves as of December 31, 2017 or January 1, 2018, as applicable. All reserves estimates involve some degree of uncertainty. For a description of the risks relating to reserves and reserves estimates, see “Item 3—Key Information—Risk Factors—Risk Factors Related to our Relationship with the Mexican Government— Information on Mexico’s hydrocarbon reserves is based on estimates, which are uncertain and subject to revisions,” “—We must make significant capital expenditures to maintain our current production levels, and to maintain, as well as increase, the proved hydrocarbon reserves assigned to us by the Mexican Government. Reductions in our income, adjustments to our capital expenditures budget and our inability to obtain financing may limit our ability to make capital investments” and “—The Mexican nation, not us, owns the hydrocarbon reserves located in the subsoil in Mexico and our right to continue to extract these reserves is subject to the approval of the Ministry of Energy.”

FORWARD-LOOKING STATEMENTS

This Form 20-F contains words, such as “believe,” “expect,” “anticipate” and similar expressions that identify forward-looking statements, which reflect our views about future events and financial performance. We have made forward-looking statements that address, among other things, our:

• exploration and production activities, including drilling;

• activities relating to import, export, refining, petrochemicals and transportation, storage and distribution of petroleum, natural gas and oil products;

• activities relating to our lines of business, including the generation of electricity;

• projected and targeted capital expenditures and other costs, commitments and revenues;

• trends in international crude oil and natural gas prices;

2

• liquidity and sources of funding, including our ability to continue operating as a going concern;

• farm-outs, joint ventures and strategic alliances with other companies; and

• the monetization of certain of our assets.

Actual results could differ materially from those projected in such forward-looking statements as a result of various factors that may be beyond our control. These factors include, but are not limited to:

• changes in international crude oil and natural gas prices;

• effects on us from competition, including on our ability to hire and retain skilled personnel;

• limitations on our access to sources of financing on competitive terms;

• our ability to find, acquire or gain access to additional reserves and to develop, either on our own or with our strategic partners, the reserves that we obtain successfully;

• our ability to successfully identify partners and enter into farm-outs, joint ventures and strategic alliances;

• liberalization of hydrocarbon prices in Mexico;

• uncertainties inherent in making estimates of oil and gas reserves, including recently discovered oil and gas reserves;

• technical difficulties;

• significant developments in the global economy;

• significant economic or political developments in Mexico and the United States;

• developments affecting the energy sector; and

• changes in our legal regime or regulatory environment, including tax and environmental regulations.

Accordingly, you should not place undue reliance on these forward-looking statements. In any event, these statements speak only as of their dates, and we undertake no obligation to update or revise any of them, whether as a result of new information, future events or otherwise.

For a discussion of important factors that could cause actual results to differ materially from those contained in any forward-looking statement, see “Item 3—Key Information—Risk Factors.”

3

4

PART I

Item 1. Identity of Directors, Senior Management and Advisers

Not applicable.

Item 2. Offer Statistics and Expected Timetable

Not applicable.

Item 3. Key Information

SELECTED FINANCIAL DATA

The selected statement of comprehensive income (loss), statement of financial position and cash flows data set forth below as of and for the five years ended December 31, 2017 have been derived from, and should be read in conjunction with, our consolidated financial statements as of December 31, 2016 and 2017 and for the years ended December 31, 2015, 2016 and 2017, which are included in Item 18 of this report. Our consolidated financial statements for each of the fiscal years ended December 31, 2013, 2014, 2015, 2016 and 2017 were audited by Castillo Miranda y Compañía, S.C. (which we refer to as BDO Mexico), an independent registered public accounting firm. Certain amounts in the consolidated financial statements for the years ended December 31, 2013, 2014, 2015 and 2016 have been reclassified to conform the presentation of the amounts in the consolidated financial statements for the year ended December 31, 2017. These reclassifications are not significant to the consolidated financial statements and had no impact on our consolidated net income (loss).

As detailed below, for the years ended December 31, 2015, 2016 and 2017, we recognized a net loss of Ps. 712.6 billion, Ps. 191.1 billion and Ps. 280.9 billion, respectively. In addition, we had negative equity as of December 31, 2016 and 2017 of Ps. 1,233.0 billion and Ps. 1,502.4 billion, respectively, which resulted in a negative working capital of Ps. 68.4 billion and Ps. 25.6 billion, respectively; and cash flows from operating activities of Ps. 63.4 billion for the year ended December 31, 2017. This has led our independent auditors to state in their most recent audit report that there is material uncertainty that may cast significant doubt on our ability to continue as a going concern. Accordingly, we have prepared our consolidated financial statements on a going concern basis, which assumes that we can meet our payment obligations. For more information on the actions that we are taking to face these negative trends, see “Item 5—Operating and Financial Review and Prospects—Overview” and “Item 5—Operating and Financial Review and Prospects—Liquidity and Capital Resources.”

5

Selected Financial Data of PEMEX

	Year ended December 31,(1)
	2013			2014			2015			2016			2017			2017(2)
	(in millions of pesos, except ratios)															(in millions of U.S. dollars)
Statement of Comprehensive Income (Loss) Data
Net sales		Ps. 1,608,205			Ps. 1,586,728			Ps. 1,161,760			Ps. 1,074,093			Ps. 1,397,030		U.S.$	70,604
Operating income		727,622			615,480			(154,387	)		424,350			104,725			5,293
Financing income		8,736			3,014			14,991			13,749			16,166			817
Financing cost		(39,586	)		(51,559	)		(67,774	)		(98,844	)		(117,645	)		(5,946	)
Derivative financial instruments (cost) income—Net		1,311			(9,439	)		(21,450	)		(14,000	)		25,338			1,281
Exchange (loss) gain—Net		(3,951	)		(76,999	)		(154,766	)		(254,012	)		23,184			1,172
Net (loss) income for the period		(170,058	)		(265,543	)		(712,567	)		(191,144	)		(280,851	)		(14,194	)
Statement of Financial Position Data (end of period)
Cash and cash equivalents		80,746			117,989			109,369			163,532			97,852			4,945
Total assets		2,047,390			2,128,368			1,775,654			2,329,886			2,132,002			107,749
Long-term debt		750,563			997,384			1,300,873			1,807,004			1,880,666			95,047
Total long-term liabilities		1,973,446			2,561,930			2,663,922			3,136,704			3,245,227			164,011
Total equity (deficit)		(185,247	)		(767,721	)		(1,331,676	)		(1,233,008	)		(1,502,352	)		(75,927	)
Statement of Cash Flows
Depreciation and amortization		148,492			143,075			167,951			150,439			156,705			7,920
Acquisition of wells, pipelines, properties, plant and equipment(3)		245,628			230,679			253,514			151,408			91,859			4,642
Other Financial Data
Ratio of earnings to fixed charges(4)(5)		—			—			—			—			—			—

(1) Includes Petróleos Mexicanos, the subsidiary entities and the subsidiary companies listed in Note 4 to our consolidated financial statements included herein.

(2) Translations into U.S. dollars of amounts in pesos have been made at the exchange rate established by the Ministry of Finance and Public Credit for accounting purposes of Ps. 19.7867 = U.S. $1.00 at December 31, 2017. Such translations should not be construed as a representation that the peso amounts have been or could be converted into U.S. dollar amounts at the foregoing or any other rate.

(3) Includes capitalized financing cost. See Note 12 to our consolidated financial statements included herein and “Item 5—Operating and Financial Review and Prospects—Liquidity and Capital Resources.”

(4) Earnings, for this purpose, consist of pre-tax income (loss) from continuing operations before income from equity investees, plus fixed charges, minus interest capitalized during the period, plus the amortization of capitalized interest during the period and plus dividends received on equity investments. Pre-tax income (loss) is calculated after the deduction of hydrocarbon duties, but before the deduction of the hydrocarbon income tax and other income taxes. Fixed charges for this purpose consist of the sum of interest expense plus interest capitalized during the period, plus amortization premiums related to indebtedness and plus the estimated interest within rental expense. Fixed charges do not take into account exchange gain or loss attributable to our indebtedness.

(5) Earnings for the years ended December 31, 2013, 2014, 2015, 2016 and 2017 were insufficient to cover fixed charges. The amount by which fixed charges exceeded earnings was Ps. 165,217 million, Ps. 283,640 million, Ps. 765,161 million, Ps. 209,148 million and Ps. 289,033 million for the years ended December 31, 2013, 2014, 2015, 2016 and 2017 respectively.

Source: PEMEX’s consolidated financial statements, prepared in accordance with IFRS, as it relates to the selected statements of comprehensive income, statement of financial position and statement of cash flows data; and Petróleos Mexicanos, as it relates to other financial data.

6

EXCHANGE RATES

The following table sets forth, for the periods indicated, the high, low, average and period-end exchange rates for the purchase of U.S. dollars, expressed in pesos per U.S. dollar. These rates have not been restated in constant currency units.

Period	Exchange Rate
	High		Low		Average(1)		Period End
Year Ended December 31,
2013		13.433		11.976		12.857		13.098
2014		14.794		12.846		13.370		14.750
2015		17.358		14.564		15.873		17.195
2016		20.842		17.190		18.667		20.617
2017		21.891		17.478		18.884		19.640
November 2017		19.257		18.513		18.931		18.634
December 2017		19.733		18.620		19.176		19.640
2018
January 2018		19.484		18.488		18.912		18.622
February 2018		18.901		18.360		18.647		18.841
March 2018		18.864		18.168		18.590		18.168
April 2018(2)		18.615		17.971		18.208		18.615

(1) Average of month-end rates, except for 2017 and 2018 monthly exchange rates.

(2) For the period from April 1, 2018 to April 20, 2018.

Source: Noon buying rate for cable transfers in New York reported by the Federal Reserve.

The noon buying rate for cable transfers in New York reported by the Federal Reserve on April 20, 2018 was Ps. 18.615 = U.S. $1.00.

7

RISK FACTORS

Risk Factors Related to Our Operations

Crude oil and natural gas prices are volatile and low crude oil and natural gas prices adversely affect our income and cash flows and the amount of hydrocarbon reserves that we have the right to extract and sell.

International crude oil and natural gas prices are subject to global supply and demand and fluctuate due to many factors beyond our control. These factors include competition within the oil and natural gas industry, the prices and availability of alternative sources of energy, international economic trends, exchange rate fluctuations, expectations of inflation, domestic and foreign laws and government regulations, political and other events in major oil and natural gas producing and consuming nations and actions taken by oil exporting countries, trading activity in oil and natural gas and transactions in derivative financial instruments (which we refer to as DFIs) related to oil and gas.

When international crude oil, petroleum product and/or natural gas prices are low, we generally earn less revenue and, therefore, generate lower cash flows and earn less income before taxes and duties because our costs remain roughly constant. Conversely, when crude oil, petroleum product and natural gas prices are high, we earn more revenue and our income before taxes and duties increases. Crude oil export prices, which had generally traded above U.S. $75.00 per barrel since October 2009 and traded above U.S. $100.00 per barrel as of July 30, 2014, began to fall in August 2014. After a gradual decline that resulted in per barrel prices falling to U.S. $91.16 at September 30, 2014, this decline sharply accelerated in October 2014 and prices fell to U.S. $53.27 per barrel at the end of 2014. The weighted average Mexican crude oil export price fell further in subsequent years, down to U.S. $26.54 per barrel by the end of December 2015 and to U.S. $18.90 per barrel on January 20, 2016, the lowest in twelve years, before rebounding to U.S. $46.53 per barrel on December 28, 2016. In 2017, crude oil export prices began to stabilize and during 2017 the weighted average Mexican crude oil export price was approximately U.S. $46.73 per barrel, rising to U.S. $56.19 per barrel on December 29, 2017. During the first three months of 2018, the weighted average Mexican crude oil price was U.S. $56.82 per barrel, an increase of U.S. $10.94 per barrel as compared to the 2017 weighted average Mexican crude oil export price. As of April 27, 2018, the weighted average Mexican crude oil export price was U.S. $60.89 per barrel. While prices have begun to stabilize or even trend upwards, they still remain significantly lower than 2014 levels. Any future decline in international crude oil and natural gas prices will have a similar negative impact on our results of operations and financial condition. These fluctuations may also affect estimates of the amount of Mexico’s hydrocarbon reserves that we have the right to extract and sell, which could affect our future production levels. See “—Risk Factors Related to our Relationship with the Mexican Government—Information on Mexico’s hydrocarbon reserves is based on estimates, which are uncertain and subject to revisions” below and “Item 11—Quantitative and Qualitative Disclosures About Market Risk—Changes in Exposure to Main Risks—Market Risk—Hydrocarbon Price Risk.”

We have a substantial amount of indebtedness and other liabilities and are exposed to liquidity constraints, which could make it difficult for us to obtain financing on favorable terms and could adversely affect our financial condition, results of operations and ability to repay our debt and, ultimately, our ability to operate as a going concern.

We have a substantial amount of debt, which we have incurred primarily to finance the capital expenditures needed to carry out our capital investment projects. Due to our heavy tax burden, our cash flow from operations in recent years has not been sufficient to fund our capital expenditures and other expenses and, accordingly, our debt has significantly increased and our working capital has decreased. The sharp decline in oil prices that began in late 2014 has had a negative impact on our ability to generate positive cash flows, which, together with our continued heavy tax burden and increased competition from the private sector, has further exacerbated our ability to fund our capital expenditures and other expenses from cash flow from operations. Therefore, in order to develop our hydrocarbon reserves and amortize scheduled debt maturities, we will need to raise financing from a broad range of funding sources, in addition to implementing the efficiency and cost-cutting initiatives described in this annual report.

8

As of December 31, 2017, our total indebtedness, including accrued interest, was approximately Ps. 2,037.9 billion (U.S. $103.0 billion), in nominal terms, which represents a 2.8% increase compared to our total indebtedness, including accrued interest, of approximately Ps. 1,983.2 billion (U.S. $96.0 billion) as of December 31, 2016. 25.8% of our existing debt as of December 31, 2017, or Ps. 526.5 billion (U.S. $26.6 billion), is scheduled to mature in the next three years. As of December 31, 2017, we had a negative working capital of Ps. 25.6 billion (U.S. $1.3 billion). Our level of debt may increase further in the short or medium term as a result of new financing activities or depreciation of the peso as compared to the U.S. dollar, and may have an adverse effect on our financial condition, results of operations and liquidity position. To service our debt, we have relied and may continue to rely on a combination of cash flows provided by our operations, drawdowns under our available credit facilities and the incurrence of additional indebtedness, including the refinancing of our existing indebtedness. See “Item 5—Operating and Financial Review and Prospects—Liquidity and Capital Resources—Overview—Changes to Our Business Plan.”

Certain rating agencies have expressed concerns regarding: (1) our heavy tax burden, (2) the total amount of our debt; (3) the significant increase in our indebtedness over the last several years; (4) our negative free cash flow during 2016, primarily resulting from our significant capital investment projects and the low price of oil; (5) the natural decline of certain of our oil fields and lower quality of crude oil; (6) our substantial unfunded reserve for retirement pensions and seniority premiums, which was equal to Ps. 1,258.4 billion (U.S. $63.6 billion) as of December 31, 2017; and (7) the resilience of our operating expenses notwithstanding the sharp decline in oil prices that began in late 2014. On August 3, 2017, Fitch Ratings affirmed our credit rating of “BBB+” in both global local and global foreign currency and modified its outlook from negative to stable. On December 18, 2017, Standard & Poor’s affirmed the outlook for our credit ratings as stable and affirmed our global foreign currency credit rating as “BBB+”, but lowered our global local currency credit rating from “A” to “A-”, citing revisions to its methodology for calculating sovereign ratings. On April 12, 2018, Moody’s Investors Service announced the revision of its outlook for our credit ratings from negative to stable.

Any lowering of our credit ratings may have adverse consequences on our ability to access the financial markets and/or our cost of financing. If we were unable to obtain financing on favorable terms, this could hamper our ability to obtain further financing, invest in projects financed through debt and meet our principal and interest payment obligations with our creditors. As a result, we may be exposed to liquidity constraints and may not be able to service our debt or make the capital expenditures required to maintain our current production levels and to maintain, and increase, the proved hydrocarbon reserves assigned to us by the Mexican Government, which may adversely affect our financial condition and results of operations. See “—Risk Factors Related to our Relationship with the Mexican Government—We must make significant capital expenditures to maintain our current production levels, and to maintain, as well as increase, the proved hydrocarbon reserves assigned to us by the Mexican Government. Reductions in our income, adjustments to our capital expenditures budget and our inability to obtain financing may limit our ability to make capital investments” below.

If such constraints occur at a time when our cash flow from operations is less than the resources necessary to meet our debt service obligations, in order to provide additional liquidity to our operations, we could be forced to further reduce our planned capital expenditures, implement further austerity measures and/or sell additional non-strategic assets in order to raise funds. A reduction in our capital expenditure program could adversely affect our financial condition and results of operations. Additionally, such measures may not be sufficient to permit us to meet our obligations.

Our consolidated financial statements have been prepared under the assumption that we will continue as a going concern. However, our independent auditors have stated in their most recent report that there is material uncertainty that may cast significant doubt on our ability to continue operating as a going concern. Our consolidated financial statements do not include any adjustments that might result from the outcome of that uncertainty. If the actions we are taking to improve our financial condition, which are described in detail under “Item 5—Operating and Financial Review and Prospects—Liquidity and Capital Resources—Overview—Changes to Our Business Plan,” are not successful, we may not be able to continue operating as a going concern.

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We are an integrated oil and gas company and are exposed to production, equipment and transportation risks, cyber-attacks, failure in our information technology system, blockades to our facilities and criminal acts and deliberate acts of terror that could adversely affect our business, results of operations and financial condition.

We are subject to several risks that are common among oil and gas companies. These risks include production risks (fluctuations in production due to operational hazards, natural disasters or weather, accidents, etc.), equipment risks (relating to the adequacy and condition of our facilities and equipment) and transportation risks (relating to the condition and vulnerability of pipelines and other modes of transportation). More specifically, our business is subject to the risks of explosions in pipelines, refineries, plants, drilling wells and other facilities, oil spills, hurricanes in the Gulf of Mexico and other natural or geological disasters and accidents, fires and mechanical failures. Criminal attempts to divert our crude oil, natural gas or refined products from our pipeline network and facilities for illegal sale have resulted in explosions, property and environmental damage, injuries and loss of life.

Our operations depend on our information technology systems and therefore cybersecurity plays a key role in protecting our operations. Cyber-threats and cyber-attacks are becoming increasingly sophisticated, coordinated and costly, and could be targeted at our operations. Although we have established an information security program that helps us to prevent, detect and correct vulnerabilities, and we have not yet suffered a significant cyber-attack, if the integrity of our information technology system were to be compromised due to a cyber-attack, or due to the negligence or misconduct of our employees, our business operations could be disrupted or even paralyzed and our proprietary information could be lost or stolen. As a result of these risks, we could face, among other things, regulatory action, legal liability, damage to our reputation, a significant reduction in revenues, an increase in costs, a shutdown of operations, or loss of our investments in areas affected by such cyber-attacks, which in turn could have a material adverse effect on our reputation, results of operations and financial condition.

Our facilities are also subject to the risk of sabotage, terrorism and blockades. For example, in early 2017 we experienced widespread demonstrations, including blockades, as a result of the Mexican Government’s increase in fuel prices during 2017, which prevented us from accessing certain of our supply terminals and caused gasoline shortages at several retail service stations in Mexico. The occurrence of these incidents related to the production, processing and transportation of oil and gas products could result in personal injuries, loss of life, environmental damage from the subsequent containment, clean-up and repair expenses, equipment damage and damage to our facilities, which in turn could adversely affect our business, results of operations and financial condition.

We purchase comprehensive insurance policies covering most of these risks; however, these policies may not cover all liabilities, and insurance may not be available for some of the consequential risks. There can be no assurance that significant incidents will not occur in the future, that insurance will adequately cover the entire scope or extent of our losses or that we we will not be held responsible for such incidents. The occurrence of a significant incident or unforeseen liability for which we are not fully insured or for which insurance recovery is significantly delayed could have a material adverse effect on our results of operations and financial condition. See “Item 4—Information on the Company—Business Overview—PEMEX Corporate Matters—Insurance.”

Developments in the oil and gas industry and other factors may result in substantial write-downs of the carrying amount of certain of our assets, which could adversely affect our operating results and financial condition.

We evaluate on an annual basis, or more frequently where the circumstances require, the carrying amount of our assets for possible impairment. Our impairment tests are performed by a comparison of the carrying amount of an individual asset or a cash-generating unit with its recoverable amount. Whenever the recoverable amount of an individual asset or cash-generating unit is less than its carrying amount, an impairment loss is recognized to reduce the carrying amount to the recoverable amount.

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Changes in the economic, regulatory, business or political environment in Mexico or other markets where we operate, such as the liberalization of fuel prices pursuant to energy reform and the significant decline in international crude oil and gas prices in recent years, among other factors, may result in the recognition of impairment charges in certain of our assets. Due to the decline in oil prices, we have performed impairment tests of our non-financial assets (other than inventories and deferred taxes) at the end of each quarter. As of December 31, 2015 and 2016, we recognized an impairment charge of Ps. 477,945 million and a net reversal of impairment in the amount of Ps. 331,314 million, respectively. As of December 31, 2017, we recognized an impairment charge of Ps. 151,444 million. See Note 12(e) to our consolidated financial statements for further information about the impairment of certain of our assets. Future developments in the economic environment, in the oil and gas industry and other factors could result in further substantial impairment charges, adversely affecting our operating results and financial condition.

Increased competition in the energy sector due to the current legal framework in Mexico could adversely affect our business and financial performance.

The Constitución Política de los Estados Unidos Mexicanos (Political Constitution of the United Mexican States or the “Mexican Constitution”) and the Ley de Hidrocarburos (Hydrocarbons Law) allows other oil and gas companies, in addition to us, to carry out certain activities related to the energy sector in Mexico, including exploration and production activities, and the import and sale of gasoline. As a result, we face competition for the right to explore and develop new oil and gas reserves in Mexico. We will also likely face competition in connection with certain refining, transportation and processing activities. In addition, increased competition could make it difficult for us to hire and retain skilled personnel. For more information, see “Item 4—Information on the Company—History and Development—Energy Reform.” While we have not yet experienced significant adverse effects from increased competition, we expect competition to increase further and there can be no assurances that we will not experience such adverse effects in the future. If we are unable to compete successfully with other oil and gas companies in the energy sector in Mexico, our results of operations and financial condition may be adversely affected.

We are increasingly participating in strategic alliances, joint ventures and other joint arrangements. These arrangements may not perform as expected, which could harm our reputation and have an adverse effect on our business, results of operations and financial condition.

In response to the energy reform, we have entered into and may in the future enter into strategic alliances, joint ventures and other joint arrangements. These arrangements are intended to reduce risks in exploration and production, refining, transportation and processing activities. Our partners in such arrangements may, as a result of financial or other difficulties, be unable or unwilling to fulfill their financial or other obligations under our agreements, threatening the viability of the relevant project. In addition, our partners may have inconsistent or opposing economic or business interests and take action contrary to our policies or objectives, which could be to our overall detriment. If our strategic alliances, joint ventures and other joint arrangements do not perform as expected, our reputation may be harmed and our business, financial condition and results of operations could be adversely affected.

We are subject to Mexican and international anti-corruption, anti-bribery and anti-money laundering laws. Our failure to comply with these laws could result in penalties, which could harm our reputation and have an adverse effect on our business, results of operations and financial condition.

We are subject to Mexican and international anti-corruption, anti-bribery and anti-money laundering laws. See “Item 4—Information on the Company—General Regulatory Framework.” Although we maintain policies and processes intended to comply with these laws, including the review of our internal control over financial reporting, we are subject to the risk that our employees, contractors or any person doing business with us may engage in fraudulent activity, corruption or bribery, circumvent or override our internal controls and procedures or misappropriate or manipulate our assets for their personal or business advantage to our detriment. We have in

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place a number of systems for identifying, monitoring and mitigating these risks, but our systems may not be effective and we cannot ensure that these compliance policies and processes will prevent intentional, reckless or negligent acts committed by our officers or employees. Any failure – real or perceived – by our officers or employees to comply with applicable governance or regulatory obligations could harm our reputation, limit our ability to obtain financing and otherwise have a material adverse effect on our business, financial condition and results of operations.

If we fail to comply with any applicable anti-corruption, anti-bribery or anti-money laundering laws, we and our officers and employees may be subject to criminal, administrative or civil penalties and other measures, which could have material adverse effects on our reputation, business, financial condition and results of operations. Any investigation of potential violations of anti-corruption, anti-bribery or anti-money laundering laws by governmental authorities in Mexico or other jurisdictions could result in an inability to prepare our consolidated financial statements in a timely manner and could adversely impact our reputation, ability to access financial markets and ability to obtain contracts, assignments, permits and other government authorizations necessary to participate in our industry, which, in turn, could have adverse effects on our business, results of operations and financial condition.

Our compliance with environmental regulations in Mexico could result in material adverse effects on our results of operations.

A wide range of general and industry-specific Mexican federal and state environmental laws and regulations apply to our operations; these laws and regulations are often difficult and costly to comply with and carry substantial penalties for non-compliance. This regulatory burden increases our costs because it requires us to make significant capital expenditures and limits our ability to extract hydrocarbons, resulting in lower revenues. For an estimate of our accrued environmental liabilities, see “Item 4—Information on the Company—Environmental Regulation—Environmental Liabilities.” Growing international concern over greenhouse gas emissions and climate change could result in new laws and regulations that could adversely affect our results of operations and financial condition. International agreements, including the Paris Agreement approved by the Mexican Government, contemplate coordinated efforts to combat climate change. We may become subject to market changes, including carbon taxes, efficiency standards, cap-and-trade and emission allowances and credits. These measures could increase our operating and maintenance costs, increase the price of our hydrocarbon products and possibly shift consumer demand to lower-carbon sources. See “Item 4—Environmental Regulation —Climate Change” for more information on the Mexican Government’s current legal and regulatory framework for combatting climate change.

Risk Factors Related to Mexico

Economic conditions and government policies in Mexico and elsewhere may have a material impact on our operations.

A deterioration in Mexico’s economic condition, social instability, political unrest or other adverse social developments in Mexico could adversely affect our business and financial condition. Those events could also lead to increased volatility in the foreign exchange and financial markets, thereby affecting our ability to obtain new financing and service our debt. Additionally, the Mexican Government announced budget cuts in November 2015, February 2016 and September 2016 in response to declines in international crude oil prices, and it may cut spending in the future. See “—Risk Factors Related to our Relationship with the Mexican Government—The Mexican Government controls us and it could limit our ability to satisfy our external debt obligations or could reorganize or transfer us or our assets” below. Any new budget cuts could adversely affect the Mexican economy and, consequently, our business, financial condition, operating results and prospects.

In the past, Mexico has experienced several periods of slow or negative economic growth, high inflation, high interest rates, currency devaluation and other economic problems. These problems may worsen or reemerge,

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as applicable, in the future and could adversely affect our business and ability to service our debt. A worsening of international financial or economic conditions, such as a slowdown in growth or recessionary conditions in Mexico’s trading partners, including the United States, or the emergence of a new financial crisis, could have adverse effects on the Mexican economy, our financial condition and our ability to service our debt.

Changes in Mexico’s exchange control laws may hamper our ability to service our foreign currency debt.

The Mexican Government does not currently restrict the ability of Mexican companies or individuals to convert pesos into other currencies. However, we cannot provide assurances that the Mexican Government will maintain its current policies with regard to the peso. In the future, the Mexican Government could impose a restrictive exchange control policy, as it has done in the past. Mexican Government policies preventing us from exchanging pesos into U.S. dollars could hamper our ability to service our foreign currency obligations, including our debt, the majority of which is denominated in currencies other than pesos.

Mexico has experienced a period of increasing criminal activity, which could affect our operations.

In recent years, Mexico has experienced a period of increasing criminal activity, primarily due to the activities of drug cartels and related criminal organizations. In addition, the development of the illicit market in fuels in Mexico has led to increases in theft and illegal trade in the fuels that we produce. In response, the Mexican Government has implemented various security measures and has strengthened its military and police forces, and we have also established various strategic measures aimed at decreasing incidents of theft and other criminal activity directed at our facilities and products. See “Item 8—Financial Information—Legal Proceedings—Actions Against the Illicit Market in Fuels.” Despite these efforts, criminal activity continues to exist in Mexico, some of which may target our facilities and products. These activities, their possible escalation and the violence associated with them, in an extreme case, may have a negative impact on our financial condition and results of operations.

Economic and political developments in Mexico and the United States may adversely affect Mexican economic policy and, in turn, PEMEX’s operations.

Political events in Mexico may significantly affect Mexican economic policy and, consequently, our operations. Enrique Peña Nieto, a member of the Partido Revolucionario Institucional (Institutional Revolutionary Party or PRI), was elected President of Mexico and took office on December 1, 2012. As of the date of this annual report, no political party holds a simple majority in either house of the Mexican Congress.

Presidential and federal congressional elections in Mexico will be held in July 2018. The Mexican presidential election will result in a change in administration, as presidential reelection is not permitted in Mexico. We cannot provide any assurances that political developments in Mexico will not have an adverse effect on the Mexican economy or oil and gas industry and, in turn, our business, results of operations and financial condition, including our ability to repay our debt.

Economic conditions in Mexico are highly correlated with economic conditions in the United States due to physical proximity and the high degree of economic activity between the two countries generally, including the trade facilitated by the North American Free Trade Agreement (“NAFTA”). As a result, political developments in the United States, including changes in the administration and governmental policies, can have an impact on the exchange rate between the U.S. dollar and the Mexican peso, economic conditions in Mexico and the global capital markets.

Since 2003, exports of petrochemical products from Mexico to the United States have enjoyed a zero-tariff rate under NAFTA and, subject to limited exceptions, exports of crude oil and petroleum products have also been free or exempt from tariffs. During 2017, our export sales to the United States amounted to Ps. 302.9 billion, representing 21.7% of total sales and 59.6% of export sales for the year. In August 2017, Mexico, the United

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States and Canada commenced renegotiation of NAFTA. As of the date of this annual report, the extent or outcome of the renegotiations, as well as the expected timing for their completion, is uncertain. Any increase of import tariffs resulting from re-negotiated NAFTA terms could make it economically unsustainable for U.S. companies to import our petrochemical, crude oil and petroleum products if they are unable to transfer those additional costs onto consumers, which would increase our expenses and decrease our revenues, even if domestic and international prices for our products remain constant. Higher tariffs on products that we export to the United States could also require us to renegotiate our contracts or lose business, resulting in a material adverse impact on our business and results of operations.

Because the Mexican economy is heavily influenced by the U.S. economy, the re-negotiation, or even termination, of NAFTA and/or other U.S. government policies that may be adopted by the U.S. administration may adversely affect economic conditions in Mexico. These developments could in turn have an adverse effect on our financial condition, results of operations and ability to repay our debt.

Risk Factors Related to our Relationship with the Mexican Government

The Mexican Government controls us and it could limit our ability to satisfy our external debt obligations or could reorganize or transfer us or our assets.

We are controlled by the Mexican Government and our annual budget may be adjusted by the Mexican Government in certain respects. Pursuant to the Petróleos Mexicanos Law, Petróleos Mexicanos was transformed from a decentralized public entity to a productive state-owned company on October 7, 2014. The Petróleos Mexicanos Law establishes a special regime governing, among other things, our budget, debt levels, administrative liabilities, acquisitions, leases, services and public works. This special regime provides Petróleos Mexicanos with additional technical and managerial autonomy and, subject to certain restrictions, with additional autonomy with respect to our budget. Notwithstanding this increased autonomy, the Mexican Government still controls us and has the power to adjust our financial balance goal, which represents our targeted net cash flow for the fiscal year based on our projected revenues and expenses, and our annual wage and salary expenditures, subject to the approval of the Cámara de Diputados (Chamber of Deputies).

The adjustments to our annual budget mentioned above may compromise our ability to develop the reserves assigned to us by the Mexican Government and to successfully compete with other oil and gas companies that enter the Mexican energy sector. See “Item 4—General Regulatory Framework” for more information about the Mexican Government’s authority with respect to our budget. In addition, the Mexican Government’s control over us could adversely affect our ability to make payments under any securities issued by Petróleos Mexicanos. Although Petróleos Mexicanos is wholly owned by the Mexican Government, our financing obligations do not constitute obligations of and are not guaranteed by the Mexican Government.

The Mexican Government’s agreements with international creditors may affect our external debt obligations. In certain past debt restructurings of the Mexican Government, Petróleos Mexicanos’ external indebtedness was treated on the same terms as the debt of the Mexican Government and other public-sector entities, and it may be treated on similar terms in any future debt restructuring. In addition, Mexico has entered into agreements with official bilateral creditors to reschedule public-sector external debt. Mexico has not requested restructuring of bonds or debt owed to multilateral agencies.

The Mexican Government has the power, if the Mexican Constitution and federal law were further amended, to further reorganize our corporate structure, including a transfer of all or a portion of our assets to an entity not controlled, directly or indirectly, by the Mexican Government. See “—Risk Factors Related to Mexico” above.

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We pay significant taxes and duties to the Mexican Government, and, if certain conditions are met, we may be required to pay a state dividend, which may limit our capacity to expand our investment program or negatively impact our financial condition generally.

We are required to make significant payments to the Mexican Government, including in the form of taxes and duties, which may limit our ability to make capital investments. In 2017, approximately 31.7% of our sales revenues was used for payments to the Mexican Government in the form of taxes and duties, which constituted a substantial portion of the Mexican Government’s revenues.

The Secondary Legislation includes changes to the fiscal regime applicable to us, particularly with respect to the exploration and production activities that we carry out in Mexico. As of 2016, we have the obligation, subject to the conditions set forth in the Petróleos Mexicanos Law, to pay a state dividend to the Mexican Government. We were not required to pay a state dividend in 2016 or 2017 and are not required to do so in 2018. See “Item 8—Financial Information—Dividends” for more information. Although the changes to the fiscal regime applicable to us are designed in part to reduce the Mexican Government’s reliance on payments made by us, we cannot provide assurances that we will not be required to continue to pay a large proportion of our sales revenue to the Mexican Government. See “Item 4—Information on the Company—Taxes, Duties and Other Payments to the Mexican Government—Fiscal Regime.” In addition, the Mexican Government may change the applicable rules in the future.

The Mexican Government has historically imposed price controls in the domestic market on our products.

The Mexican Government has from time to time imposed price controls on the sales of natural gas, liquefied petroleum gas, gasoline, diesel, gas oil intended for domestic use, fuel oil and other products. As a result of these price controls, we have not been able to pass on all of the increases in the prices of our product purchases to our customers in the domestic market when the peso depreciates in relation to the U.S. dollar. A depreciation of the peso increases our cost of imported oil and gas products, without a corresponding increase in our revenues unless we are able to increase the price at which we sell products in Mexico.

In accordance with the Ley de Ingresos de la Federación para el Ejercicio Fiscal de 2017 (2017 Federal Revenue Law), during 2017 the Mexican Government gradually removed price controls on gasoline and diesel as part of the liberalization of fuel prices in Mexico. As of the date of this annual report, sales prices of gasoline and diesel have been fully liberalized and are determined by the free market. For more information, see “Item 4—Information on the Company—Business Overview—Industrial Transformation.” However, we do not control the Mexican Government’s domestic policies and the Mexican Government could impose additional price controls on the domestic market in the future. The imposition of such price controls would adversely affect our results of operations. For more information, see “Item 4—Information on the Company—Business Overview—Refining—Pricing” and “Item 4—Information on the Company—Business Overview—Gas and Basic Petrochemicals—Pricing.”

The Mexican nation, not us, owns the hydrocarbon reserves located in the subsoil in Mexico and our right to continue to extract these reserves is subject to the approval of the Ministry of Energy.

The Mexican Constitution provides that the Mexican nation, not us, owns all petroleum and other hydrocarbon reserves located in the subsoil in Mexico.

Article 27 of the Mexican Constitution provides that the Mexican Government will carry out exploration and production activities through agreements with third parties and through assignments to and agreements with us. The Secondary Legislation allows us and other oil and gas companies to explore and extract the petroleum and other hydrocarbon reserves located in Mexico, subject to assignment of rights by the Ministry of Energy and entry into agreements pursuant to a competitive bidding process.

Access to crude oil and natural gas reserves is essential to an oil and gas company’s sustained production and generation of income, and our ability to generate income would be materially and adversely affected if the

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Mexican Government were to restrict or prevent us from exploring or extracting any of the crude oil and natural gas reserves that it has assigned to us or if we are unable to compete effectively with other oil and gas companies in future bidding rounds for additional exploration and production rights in Mexico. For more information, see “—We must make significant capital expenditures to maintain our current production levels, and to maintain, as well as increase, the proved hydrocarbon reserves assigned to us by the Mexican Government. Reductions in our income, adjustments to our capital expenditures budget and our inability to obtain financing may limit our ability to make capital investments” below.

Information on Mexico’s hydrocarbon reserves is based on estimates, which are uncertain and subject to revisions.

The information on oil, gas and other reserves set forth in this annual report is based on estimates. Reserves valuation is a subjective process of estimating underground accumulations of crude oil and natural gas that cannot be measured in an exact manner; the accuracy of any reserves estimate depends on the quality and reliability of available data, engineering and geological interpretation and subjective judgment. Additionally, estimates may be revised based on subsequent results of drilling, testing and production. These estimates are also subject to certain adjustments based on changes in variables, including crude oil prices. Therefore, proved reserves estimates may differ materially from the ultimately recoverable quantities of crude oil and natural gas. Downward revisions in our reserve estimates could lead to lower future production, which could have an adverse effect on our results of operations and financial condition. See “—Risk Factors Related to Our Operations—Crude oil and natural gas prices are volatile and low crude oil and natural gas prices adversely affect our income and cash flows and the amount of hydrocarbon reserves that we have the right to extract and sell” above. We revise annually our estimates of hydrocarbon reserves that we are entitled to extract and sell, which may result in material revisions to these estimates. Our ability to maintain our long-term growth objectives for oil production depends on our ability to successfully develop our reserves, and failure to do so could prevent us from achieving our long-term goals for growth in production.

The Comisión Nacional de Hidrocarburos (National Hydrocarbon Commission, or CNH) has the authority to review and approve our estimated hydrocarbon reserves estimates and may require us to make adjustments to these estimates. A request to adjust these reserves estimates could result in our inability to prepare our consolidated financial statements in a timely manner. This could adversely impact our ability to access financial markets, obtain contracts, assignments, permits and other government authorizations necessary to participate in the crude oil and natural gas industry, which, in turn, could have an adverse effect on our business, results of operations and financial condition.

We must make significant capital expenditures to maintain our current production levels, and to maintain, as well as increase, the proved hydrocarbon reserves assigned to us by the Mexican Government. Reductions in our income, adjustments to our capital expenditures budget and our inability to obtain financing may limit our ability to make capital investments.

Because our ability to maintain, as well as increase, our oil production levels is highly dependent upon our ability to successfully develop existing hydrocarbon reserves and, in the long term, upon our ability to obtain the right to develop additional reserves, we continually invest capital to enhance our hydrocarbon recovery ratio and improve the reliability and productivity of our infrastructure. During 2017, our total proved reserves decreased by 868.1 million barrels of oil equivalent, or 10.1%, after accounting for discoveries, extensions, revisions, and delimitations, from 8,562.8 million barrels of crude oil equivalent as of December 31, 2016 to 7,694.7 million barrels of crude oil equivalent as of December 31, 2017. See “Item 4—Information on the Company—Business Overview––Exploration and Production––Reserves” for more information about the factors leading to this decline. Our crude oil production decreased by 1.0% from 2012 to 2013, by 3.7% from 2013 to 2014, by 6.7% from 2014 to 2015, by 5.0% from 2015 to 2016 and by 9.5% from 2016 to 2017, primarily as a result of the decline of the Cantarell, Crudo Ligero Marino, El Golpe-Puerto Ceiba, Bellota-Chinchorro, Antonio J. Bermúdez, Cactus-Sitio Grande, Ixtal-Manik, Chuc, Costero Terreste and Tsimín-Xux projects.

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Pursuant to energy reform in Mexico, the Mexican Government outlined a process, commonly referred to as Round Zero, for the determination of our initial allocation of rights to continue to carry out exploration and production activities in Mexico. On August 13, 2014, the Ministry of Energy granted us the right to continue to explore and develop areas that together contain 95.9% of Mexico’s estimated proved reserves of crude oil and natural gas. The development of the reserves that were assigned to us pursuant to Round Zero and subsequent bidding rounds, particularly the reserves in the deep waters of the Gulf of Mexico and in shale oil and gas fields in the Burgos basin, will demand significant capital investments and will pose significant operational challenges. Our right to develop the reserves assigned to us is conditioned on our ability to develop such reserves in accordance with our development plans, which were based on our technical, financial and operational capabilities at the time. See “Item 4—History and Development—Energy Reform—Assignment of Exploration and Production Rights.” We cannot provide assurances that we will have or will be able to obtain, in the time frame that we expect, sufficient resources or the technical capacity necessary to explore and extract the reserves that the Mexican Government assigned to us, or that it may grant to us in the future. We have reduced our capital expenditures in prior years in response to declining oil prices, and unless we are able to increase our capital expenditures, we may not be able to develop the reserves assigned to us in accordance with our development plans. We would lose the right to continue to extract these reserves if we fail to develop them in accordance with our development plans, which could adversely affect our operating results and financial condition. In addition, increased competition in the oil and gas sector in Mexico may increase the costs of obtaining additional acreage in bidding rounds for the rights to new reserves.

Our ability to make capital expenditures is limited by the substantial taxes and duties that we pay to the Mexican Government, the ability of the Mexican Government to adjust certain aspects of our annual budget, cyclical decreases in our revenues primarily related to lower oil prices and any constraints on our liquidity. The availability of financing may limit our ability to make capital investments that are necessary to maintain current production levels and decrease the proved hydrocarbon reserves that we are entitled to extract. For more information on the liquidity constraints we are exposed to, see “—We have a substantial amount of indebtedness and other liabilities and are exposed to liquidity constraints, which could make it difficult for us to obtain financing on favorable terms and could adversely affect our financial condition, results of operations and ability to repay our debt and, ultimately, our ability to operate as a going concern” above.

The energy reform has provided us with opportunities to enter into strategic alliances and partnerships, which may reduce our capital commitments and allow us to participate in projects for which we are more competitive. We have since entered into, and continue to enter into, strategic alliances, joint ventures and other joint arrangements with third parties in order to develop our reserves. If we are unable to find partners for such joint arrangements, or if our partners were to significantly default on their obligations to us, we may be unable to maintain production levels or extract from our reserves. Moreover, we cannot assure you that these strategic alliances, joint ventures and other joint arrangements will be successful or reduce our capital commitments. For more information, see “—Risk Factors Related to Pemex’s Operations—We are increasingly participating in strategic alliances, joint ventures and other joint arrangements. These arrangements may not perform as expected, which could harm our reputation and have an adverse effect on our business, results of operations and financial condition” above and “Item 4—Information on the Company—History and Development—Capital Expenditures” and “—Energy Reform.”

We may claim some immunities under the Foreign Sovereign Immunities Act and Mexican law, and your ability to sue or recover may be limited.

We are public-sector entities of the Mexican Government. Accordingly, you may not be able to obtain a judgment in a U.S. court against us unless the U.S. court determines that we are not entitled to sovereign immunity with respect to that action. Under certain circumstances, Mexican law may limit your ability to enforce judgments against us in the courts of Mexico. We also do not know whether Mexican courts would enforce judgments of U.S. courts based on the civil liability provisions of the U.S. federal securities laws. Therefore, even if you were able to obtain a U.S. judgment against us, you might not be able to obtain a judgment in Mexico

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that is based on that U.S. judgment. Moreover, you may not be able to enforce a judgment against our property in the United States except under the limited circumstances specified in the Foreign Sovereign Immunities Act of 1976, as amended. Finally, if you were to bring an action in Mexico seeking to enforce our obligations under any securities issued by Petróleos Mexicanos, satisfaction of those obligations may be made in pesos, pursuant to the laws of Mexico.

Our directors and officers, as well as some of the experts named in this annual report, reside outside the United States. Substantially all of our assets and those of most of our directors, officers and experts are located outside the United States. As a result, investors may not be able to effect service of process on our directors or officers or those experts within the United States.

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Item 4. Information on the Company

HISTORY AND DEVELOPMENT

We are the largest company in Mexico according to the June 2017 edition of Expansión magazine, and according to the November 20, 2017 issue of Petroleum Intelligence Weekly, we were the eighth largest crude oil producer and the eighteenth largest oil and gas company in the world based on data from the year 2016.

Our executive offices are located at Avenida Marina Nacional No. 329, Colonia Verónica Anzures, Ciudad de México 11300, México. Our telephone number is (52-55) 1944-2500.

In March 1938, President Lázaro Cárdenas del Río nationalized the foreign-owned oil companies that were then operating in Mexico, and the Mexican Congress established Petróleos Mexicanos through the Decreto que crea la Institución Petróleos Mexicanos (Decree that creates the entity Petróleos Mexicanos), which was published in the Official Gazette of the Federation and took effect on July 20, 1938.

In July 1992, the Ley Orgánica de Petróleos Mexicanos y Organismos Subsidiarios (Organic Law of Petróleos Mexicanos and Subsidiary Entities) took effect and, among other things, created Pemex-Exploration and Production, Pemex-Refining, Pemex-Gas and Basic Petrochemicals and Pemex-Petrochemicals as decentralized public entities of the Mexican Government with the legal authority to own property and conduct business in their own names. Each of the subsidiary entities had the characteristics of a subsidiary of Petróleos Mexicanos.

Energy Reform

Energy Reform Decree

On December 20, 2013, amendments to Articles 25, 27 and 28 of the Mexican Constitution were signed into law by President Enrique Peña Nieto and published in the Official Gazette of the Federation. We refer to this as the Energy Reform Decree. The Energy Reform Decree, which includes transitional articles setting forth the general framework and timeline for the related secondary legislation, took effect on December 21, 2013.

Secondary Legislation

On August 11, 2014, the secondary legislation was published pursuant to the Energy Reform Decree in the Official Gazette of the Federation. We refer in this annual report to this legislation as the Secondary Legislation. The Secondary Legislation includes nine new laws, of which the following are most relevant to our operations:

• The new Petróleos Mexicanos Law, which took effect, with the exception of certain provisions, on October 7, 2014 and repealed the previous Petróleos Mexicanos Law, which had been effective as of November 29, 2008;

• Hydrocarbons Law, which took effect on August 12, 2014 and repealed the Ley Reglamentaria del Artículo 27 Constitucional en el Ramo del Petróleo (Regulatory Law to Article 27 of the Mexican Constitution Concerning Petroleum Affairs, which we refer to as the Regulatory Law); and

• Ley de Ingresos sobre Hidrocarburos (Hydrocarbons Revenue Law).

Together, the Hydrocarbons Law and the Hydrocarbons Revenue Law establish the legal framework for the exploration and production of oil and gas through assignments and contracts, as well as the new fiscal regime through which the Mexican Government will collect revenues from participants in the Mexican oil and gas industry. The Hydrocarbons Law empowers the Ministry of Energy to determine the appropriate contract model for each area that is subject to a competitive bidding process, while the Ministry of Finance and Public Credit is responsible for determining the economic and fiscal terms of each contract. See “—Taxes, Duties and Other

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Payments to the Mexican Government—Fiscal Regime” below in this Item 4. The following arrangements comprise the new contractual regime established by the Secondary Legislation for upstream activities:

• licenses, pursuant to which a license holder is entitled to the oil and gas that are extracted from the subsoil;

• production-sharing contracts, pursuant to which a contractor is entitled to receive a percentage of production;

• profit-sharing contracts, pursuant to which a contractor is entitled to receive a percentage of the profit from the sale of the extracted oil and gas; and

• service contracts, pursuant to which a contractor would receive cash payments for services performed (service contracts, together with licenses, production-sharing contracts and profit-sharing contracts are known as the contracts for the exploration and production of oil and gas, collectively referred to as contracts for exploration and production).

For midstream and downstream activities, including oil refining and natural gas processing, the Hydrocarbons Law establishes a permit regime that is granted by the Ministry of Energy and the Comisión Reguladora de Energía (Energy Regulatory Commission, or CRE), as applicable. The Hydrocarbons Law also sets forth the process by which entities may apply for these permits. The CRE began issuing permits for the retail sale of gasoline and diesel fuel in 2016.

Legal Regime for Petróleos Mexicanos

As part of energy reform, Petróleos Mexicanos was transformed from a decentralized public entity into a productive state-owned company on October 7, 2014—the day on which the new Petróleos Mexicanos Law took effect, with the exception of certain provisions. As a productive state-owned company, Petróleos Mexicanos remains wholly owned by the Mexican Government and has the corporate purpose of generating economic value and increasing the income of the Mexican nation while adhering to principles of equity, as well as social and environmental responsibility.

On December 2, 2014, upon its determination that the new Board of Directors of Petróleos Mexicanos was performing its duties and the mechanisms for our oversight, transparency and accountability had been implemented, the Ministry of Energy formally announced in the Official Gazette of the Federation that the special regime provided for in the Petróleos Mexicanos Law, which governs Petróleos Mexicanos’ activities relating to productive state-owned subsidiaries, affiliates, compensation, assets, administrative liabilities, budget, debt levels and the state dividend, had taken effect. On June 10, 2015, the Disposiciones Generales de Contratación para Petróleos Mexicanos y Sus Empresas Productivas Subsidiarias (General Provisions for Contracting for Petróleos Mexicanos and its Productive State-Owned Subsidiaries) were published in the Official Gazette of the Federation, and on June 11, 2015, the special regime for acquisitions, leases, services and public works became effective.

Corporate Reorganization

In accordance with the transitional articles of the Petróleos Mexicanos Law, on November 18, 2014, the Board of Directors of Petróleos Mexicanos approved the Director General’s proposal for our corporate reorganization. In our corporate reorganization, the four existing subsidiary entities of Petróleos Mexicanos were transformed into two new productive state-owned subsidiaries—Pemex Exploration and Production and Pemex Industrial Transformation—and five new productive state-owned subsidiaries—Pemex Drilling and Services, Pemex Logistics, Pemex Cogeneration and Services, Pemex Fertilizers and Pemex Ethylene—were created. Each of these productive state-owned subsidiaries is a legal entity empowered to own property and carry on business in its own name and has technical and operational autonomy, subject to the central coordination and strategic direction of Petróleos Mexicanos.

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On March 27, 2015, the Board of Directors of Petróleos Mexicanos adopted acuerdos de creación (creation resolutions) for each of the new productive state-owned subsidiaries, all of which were subsequently published in the Official Gazette of the Federation on April 28, 2015.

The principal lines of business of the new productive state-owned subsidiaries are as follows:

• Pemex Exploration and Production, formed on June 1, 2015 as a successor to Pemex-Exploration and Production, explores for, extracts, transports, stores and markets crude oil and natural gas;

• Pemex Cogeneration and Services, formed on June 1, 2015, generates, supplies and trades electric and thermal energy;

• Pemex Drilling and Services, formed on August 1, 2015, performs drilling and well repair services;

• Pemex Fertilizers, formed on August 1, 2015, integrates the ammonia production chain up to the point of sale of fertilizers;

• Pemex Ethylene, formed on August 1, 2015, separates the ethylene business from our petrochemicals segment in order to take advantage of the integration of the ethylene production chain and distributes and trades other gases, including methane and propylene;

• Pemex Logistics, formed on October 1, 2015, provides land, maritime and pipeline transportation, storage and distribution to us and third parties; and

• Pemex Industrial Transformation, formed on November 1, 2015 as a successor of Pemex-Refining, Pemex-Gas and Basic Petrochemicals and Pemex-Petrochemicals, refines petroleum products and derivatives; processes natural gas, natural gas liquids, artificial gas and derivatives and engages in industrial petrochemical processes.

Capital Expenditures

The following table shows our capital expenditures, excluding non-capitalizable maintenance, for each of the three years ended December 31, 2017, and the budget for these expenditures for 2018. Capital expenditure amounts are derived from our budgetary records, which are prepared on a cash basis. Accordingly, these capital expenditure amounts do not correspond to capital expenditure amounts included in our consolidated financial statements prepared in accordance with IFRS. The following table presents our capital expenditures by subsidiary. For the year ended December 31, 2015, we have included capital expenditures made by the subsidiary entities prior to our recent corporate reorganization, and for the new productive state-owned subsidiaries, capital expenditures made after their creation. For the year ended December 31, 2016 and 2017, and for the 2018 budget, we have included capital expenditures made by, or expected to be made by the productive state-owned subsidiaries.

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Capital Expenditures and Budget by Subsidiary

	Year ended December 31,						Budget 2018(1)
	2015		2016		2017
	(in millions of pesos)(2)
Pemex-Exploration and Production(3)		Ps. 153,110		Ps. 137,242		Ps. 85,491		Ps. 81,765
Pemex Industrial Transformation(4)		4,952		33,947		18,576		18,360
Pemex Logistics(5)		631		7,015		4,917		4,449
Pemex Drilling and Services(6)		—		2,688		1,550		1,434
Pemex Ethylene(7)		426		746		618		1,786
Pemex Fertilizers(8)		205		379		264		444
Pemex-Refining		34,152		n.a.		n.a.		n.a.
Pemex-Gas and Basic Petrochemicals		5,070		n.a.		n.a.		n.a.
Pemex-Petrochemicals		2,604		n.a.		n.a.		n.a.
Pemex Cogeneration and Services		—		—		—		—
Petróleos Mexicanos		2,157		1,004		1,609		4,978
Total capital expenditures		Ps. 203,307		Ps. 183,021		Ps. 113,025		Ps. 113,216

Note: Numbers may not total due to rounding.

n.a. Not available.

(1) Budget presented to the Board of Directors of Petróleos Mexicanos on March 5, 2018.

(2) Figures are stated in nominal pesos.

(3) For the year ended December 31, 2015, this includes capital expenditures made by Pemex-Exploration and Production and the new productive state-owned subsidiary Pemex Exploration and Production.

(4) Figures for the year ended December 31, 2015 include capital expenditures after November 1, 2015, when Pemex Industrial Transformation was formed.

(5) Figures for the year ended December 31, 2015 include capital expenditures after October 1, 2015, when Pemex Logistics was formed.

(6) For the year ended December 31, 2015, capital expenditures for Pemex Drilling and Services were allocated under Pemex Exploration and Production.

(7) Figures for the year ended December 31, 2015 include capital expenditures after October 1, 2015, when Pemex Ethylene was formed.

(8) Figures for the year ended December 31, 2015 include capital expenditures after October 1, 2015, when Pemex Fertilizers was formed.

Source: Petróleos Mexicanos.

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The following table shows our capital expenditures, excluding non-capitalizable maintenance, by segment for the years ended December 31, 2016 and 2017 and the budget for these expenditures in 2018.

Capital Expenditures by Segment

	Year ended December 31,				Budget 2018(1)
	2016		2017
	(millions of pesos)
Exploration and Production	Ps.	137,242	Ps.	85,491	Ps.	81,765
Industrial Transformation
Refining		30,501		15,988		14,376
Gas and Aromatics		3,446		2,587		3,984
Total		33,947		18,576		18,360
Logistics		7,015		4,917		4,449
Drilling and Services		2,688		1,550		1,434
Ethylene		746		618		1,786
Fertilizers		379		264		444
Cogeneration and Services		—		—		—
Corporate and other Subsidiaries		1,004		1,609		4,978
Total Capital Expenditures	Ps.	183,021	Ps.	113,025	Ps.	113,216

Note: Numbers may not total due to rounding.

(1) Budget presented to the Board of Directors of Petróleos Mexicanos on March 5, 2018.

Source: Petróleos Mexicanos.

Capital Expenditures Budget

Capital expenditures and budget by project are described under each segment below in this Item 4.

Since mid-2014, the international reference prices of crude oil have fluctuated significantly. After falling to a twelve-year low on January 20, 2016 of U.S. $18.90 per barrel, the Mexican crude oil export price rose to U.S. $46.53 at the end of 2016, and further to U.S. $56.19 per barrel on December 29, 2017. The weighted average Mexican crude oil export price for 2017 was U.S. $46.73 per barrel. Based on its estimate that the weighted average Mexican crude oil export price would be U.S. $48.50 per barrel, the Mexican Congress approved our Ps. 204.6 billion capital expenditures budget, including non-capitalizable maintenance, for 2018. Our capital expenditures budget net of non-capitalizable maintenance is Ps. 113.2 billion.

In light of the oil and gas market and global economic conditions, on November 9, 2017 the Chamber of Deputies approved a 2018 budget of Ps. 391.9 billion, including operational expenses and a financial balance goal (which we define as sales after deducting costs and expenses, investment expenses, taxes and duties, and financial debt service) of Ps. 79.4 billion. With this budget, our management expects that we will be able to maintain our medium- and long-term growth plans without the need to incur more indebtedness than the amount included in our approved financing program for 2018. The budget was based on the guiding principles of: maintaining the industrial safety and reliability of our facilities; taking advantage of the new contractual models provided by the energy reform in order to attract third-party investment; meeting our labor and financial obligations; and stabilizing our crude oil and gas production levels in the medium and long-term.

Our budget for 2018 includes a total of Ps. 113.2 billion for capital expenditures. We expect to direct Ps.81.8 billion (or 72.2% of our total capital expenditures) to exploration and production programs in 2018. This investment in exploration and production activities reflects our focus on maximizing the potential of hydrocarbon reserves and our most productive projects, the promotion of our farm-out program, which we believe will allow

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us to sustain and increase our production levels while decreasing our corresponding capital expenditures, and our intention to take advantage of the opportunities provided by the energy reform. The energy reform provides us with opportunities to form new strategic partnerships to enhance our financial, technical and operational capabilities along our entire value chain. See “—Energy Reform” above in this Item 4. We continuously review our capital expenditures portfolio in accordance with our current and future business plans and upcoming opportunities. In the upcoming years, we expect to receive financial resources from third parties who may partner with us on certain projects, a collaboration made possible following the implementation of the Secondary Legislation. See “—Energy Reform” above in this Item 4 for more information about these new opportunities.

Our main objectives for upstream investment are to maximize our long-term economic value, and to increase and improve the quality of the oil and gas reserves assigned to us, enhance Pemex Exploration and Production’s reserves recovery ratio, improve the reliability of its production and transportation infrastructure for crude oil and natural gas operations and continue to emphasize industrial safety and compliance with environmental regulations. Our 2018 budget objectives include maintaining crude oil production at levels sufficient to satisfy domestic demand and have a surplus available for export and maintaining natural gas production levels.

Our downstream investment program seeks to improve the quality of our product selection and the reliability of our logistics and distribution services, to achieve a level of efficiency similar to that of our international competitors and to continue to emphasize industrial safety and environmental compliance.

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BUSINESS OVERVIEW

Overview by Business Segment

Exploration and Production

Our exploration and production segment operates through the productive state-owned subsidiary Pemex Exploration and Production and explores for and produces crude oil and natural gas, primarily in the northeastern and southeastern regions of Mexico and offshore in the Gulf of Mexico. In nominal peso terms, our capital expenditures in exploration and production activities decreased by 37.7% in 2017. As a result of our investments in previous years, our total hydrocarbon production reached a level of approximately 999.3 million barrels of oil equivalent in 2017. Despite these investments, our crude oil production decreased by 9.5% from 2016 to 2017, averaging 1,948.3 thousand barrels per day in 2017, primarily as a result of the decline of the Cantarell, Crudo Ligero Marino, El Golpe-Puerto Ceiba, Bellota-Chinchorro, Antonio J. Bermúdez, Cactus-Sitio Grande, Ixtal-Manik, Chuc, Costero Terrestre, and Tsimín-Xux projects, which was partially offset by development of the Integral Yaxché project’s Xanab field and by repairs, stimulations and diversification of artificial systems at our onshore fields that helped maintain production levels.

Our natural gas production (excluding natural gas liquids) decreased by 12.5% from 2016 to 2017, averaging 5,068.0 million cubic feet per day in 2017. This decrease in natural gas production resulted primarily from decreased volumes in the Burgos, Crudo Ligero Marino, Ixtal-Manik, Integral Veracruz Basin, Cactus-Sitio Grande, Integral Macuspana Basin and Ogarrio-Sánchez Magallanes projects. Exploration drilling activity increased by 14.3% from 2016 to 2017, from 21 exploratory wells completed in 2016 to 24 exploratory wells completed in 2017. Development drilling activity decreased by 57.0% from 2016 to 2017, from 128 development wells completed in 2016 to 55 development wells completed in 2017. In 2017, we completed the drilling of 79 wells in total. Our drilling activity in 2017 was focused on increasing the production of crude oil and associated gas in the Ayatsil-Tekel, Chuc, Crudo Ligero Marino, El Golpe-Puerto Ceiba, Ku-Maloob-Zaap, Tsimín-Xux, Aceite Terciario del Golfo and Ogarrio-Sánchez Magallanes projects.

Our primary objectives in 2018 include: (i) maximizing profitability to ensure the sustainability of the company; (ii) increasingly taking advantage of the opportunities and flexibility provided by the energy reform; (iii) improving our performance in industrial safety and environmental protection; and (iv) increasing productivity and efficiency. We aim to meet these objectives through the following: (1) establishment of an exploration model that allows us to grow our proven, probable and possible reserves; (2) further development of business plans for the development of shale; (3) containment and reversal of production decline and increase of profitability of assignments migrated without third party participation; (4) entering into and developing existing strategic alliances, partnertships and other arrangements to attract additional investment and to expand exploration activities; (5) focus on maintenance to improve the safety of our operations; (6) improved operational efficiency and cost control; and (7) an increase in sales of our hydrocarbons. Our production goals for 2018 include producing crude oil at a level of approximately 1,930.4 thousand barrels per day and maintaining natural gas production above 4,656 million cubic feet per day. We aim to meet these production goals through exploration and development activities, increasing inventory reserves through new discoveries and reclassifications and managing the decline in field production by increasing our participation in future bidding rounds in order to enter into new partnerships and farm-outs.

Industrial Transformation

Our industrial transformation segment is comprised of two principal activities: (i) refining and (ii) gas and aromatics:

Refining

Pemex Industrial Transformation converts crude oil into gasoline, jet fuel, diesel, fuel oil, asphalts and lubricants. We also distribute and market most of these products throughout Mexico. During 2017, atmospheric

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distillation refining increased to 1,627.0 thousand barrels per day, which represents an increase of 1.6% as compared to 1,602 thousand barrels per day during 2016. In 2017, we produced 786.2 thousand barrels per day of refined products as compared to 977.2 thousand barrels per day of refined products in 2016. This decrease in refined products production was mainly due to the effects of tropical storm “Calvin” and the earthquakes that occurred in Mexico, which affected our crude oil processing in the Salina Cruz refinery. See “—Health, Safety and Environmental Performance” in this Item 4. Refined products production also decreased as a result of the implementation of a general maintenance program at our Madero refinery, which began on August 23, 2017. As a result of operational problems and natural disasters, processing of crude oil by the National Refining System decreased 17.8 %, from 933.1 million barrels per day in 2016 to 767.0 million barrels per day in 2017.

Our primary goal for 2018 is to become profitable by focusing on maximizing the value of our distillate production. We also intend to continue to take advantage of the opportunities provided by the energy reform to enter into new strategic alliances and partnerships to improve the operational performance of our plants. In addition, through an increased focus on the maintenance of our facilities, we are looking to achieve higher levels of crude oil processing and to increase the production of higher value refined products.

Gas and Aromatics

Our gas and aromatics business processes wet natural gas to produce dry natural gas, ethane, liquefied petroleum gas (LPG) and other natural gas liquids, along with aromatic derivatives chain products such as toluene, benzene and xylene. In 2017, our total sour natural gas processing capacity remained at 2016 levels of 4,523 cubic feet per day. We processed 3,237 million cubic feet of wet natural gas per day in 2017, an 11.8% decrease from the 3,672 million cubic feet per day of wet natural gas processed in 2016. We produced 280 thousand barrels per day of natural gas liquids in 2017, a 9.1% decrease from the 308 thousand barrels per day of natural gas liquids produced in 2016. We also produced 2,667 million cubic feet of dry gas (which is natural gas with a methane content of more than 90.0%) per day in 2017, 13.2% less than the 3,074 cubic feet of dry gas per day produced in 2016. We produced 622 thousand tons of aromatics and derivatives, a 33.8% decrease from 2016. The decreases in our gas and aromatics production was mainly due to a decrease in the supply of sour wet gas from our Marine and Southern regions, as well as the limited supply of sweet wet gas from the Burgos basin.

In 2018, we expect to have a lower supply of natural gas from our fields, which would require us to import higher volumes of natural gas to satisfy domestic demand. In addition, we are evaluating several alternatives for the use of our sour wet gas with high nitrogen content.

Fertilizers

Our fertilizers segment operates through the productive state-owned subsidiary Pemex Fertilizers and integrates the ammonia production chain up to the point of sale of fertilizers, including urea (produced at our Pajaritos petrochemical complex), agricultural and industrial nitrates, phosphate fertilizers and acids (produced by Fertinal).

Our strategies focus on: (1) increasing the economic value of our segment by generating diverse investment opportunities in the agricultural sector in Mexico and (2) ensuring a reliable supply of raw materials for our plants through a long-term contract that sustains operations at our four ammonia plants.

Ethylene

Our ethylene segment operates through the productive state-owned subsidiary Pemex Ethylene and takes advantage of the integration of the ethylene production chain. In 2017, we produced a total of 1,884.0 thousand tons of petrochemical products, a 25.5% decrease from the 2,528.7 thousand tons of petrochemical products produced in 2016.

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The primary goals for our ethylene segment are to streamline our operations and improve our operational reliability, and to secure a steady and reliable supply of raw materials, which will allow us to improve margins and achieve profitability.

Drilling and Services

Our drilling and services segment operates through the productive state-owned subsidiary Pemex Drilling and Services and provides drilling, completion, work-over and other services for wells in offshore and onshore fields. In 2017, this segment mainly provided completion, work-over and other drilling services to Pemex Exploration and Production, but also provided services to external clients such as Comisión Nacional del Agua (CONAGUA), Marinsa de México S.A. de C.V. (“Marinsa”), Constructora y Perforadora Latina S.A. de C.V. (“Latina”), Fieldwood Energy LLC (“Fieldwood”) and Key Energy Services (“Key Energy”).

Our well drilling activities during 2017 led to onshore discoveries. Our main discoveries were of crude oil reserves located in the Southeastern and Veracruz basins, specifically in the Northern and Southern regions. Exploration activity in the Northern region also led to the discovery of additional non-associated gas reserves in the Burgos basin. We are currently working on development plans for these new reserves.

Logistics

Our logistics segment operates through the productive state-owned subsidiary Pemex Logistics and provides land, maritime and pipeline transportation, storage and distribution services to us and other companies, including the Comisión Federal de Electricidad (Federal Electricity Commission or CFE), Aeropuertos y Servicios Auxiliares, CENAGAS, local gas stations and distributors.

During 2017, we injected approximately 1,887 thousand barrels per day of crude oil and petroleum products into our pipelines, representing a 10.9% decrease as compared to 2016 when we injected approximately 2,117 thousand barrels per day, mainly due to a reduction in crude oil processed in the National Refining System and the illicit market in fuels that caused temporary closures of certain pipelines. Of the total amount of crude oil and petroleum products that we transported in 2017, 77.1% was transported by pipeline, 7.8% by tanker and the remaining 15.1% by land transport.

During 2017, we transported 137.9 thousand barrels per day of LPG, representing a 3.5% decrease as compared to the 142.9 thousand barrels per day transported in 2016. In addition, we transported 2.3 thousand barrels per day of petrochemicals, a decrease of 30.3% as compared to the 3.3 thousand barrels per day we transported in 2016. These decreases were mainly due to a decrease in the volume of LPG transported to Pemex Industrial Transformation, primarily due to the importation of LPG by private companies, as well as decreased production of natural gas by Pemex Exploration and Production.

As of 2016, natural gas transportation is carried out by CENAGAS, with the support of Pemex Logistics through an operation and maintenance contract. During 2017, we transported approximately 5,196 million cubic feet per day of natural gas, a 4.5% decrease compared to the 5,440 million cubic feet per day we transported in 2016, mainly due to a decrease in natural gas transported to CFE and Pemex Industrial Transformation.

Cogeneration and Services

Our cogeneration and services segment operates through the productive state-owned subsidiary Pemex Cogeneration and Services and uses thermal heat and steam from our industrial processes to produce the electricity required by us, as well as to generate surplus electricity to sell to third parties in Mexico.

Our cogeneration and services segment designs construction, financing and development structures for cogeneration through alliances with third parties in close geographic proximity to our productive work centers.

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As of the date of this annual report, we have transferred certain assets of our cogeneration and services segment to Pemex Industrial Transformation.

International Trading

The international trading segment, which operates through P.M.I. Comercio Internacional, S.A. de C.V. (which we refer to as PMI), P.M.I. Trading, Ltd., P.M.I. Norteamérica, S.A. de C.V., (which, together with PMI, we collectively refer to as the “PMI Subsidiaries”) and Mex Gas International, Ltd., (which, together with the PMI Subsidiaries, we collectively refer to as the “Trading Companies”) provides us with international trading, distribution, risk management, insurance and transportation services. Certain of the Trading Companies sell, buy and transport crude oil, refined products and petrochemicals in world markets, and provide related risk management, insurance, transportation and storage services. The Trading Companies have offices in Mexico City, Houston, Amsterdam, Singapore and Madrid. Export sales are made through PMI to approximately 32 major customers in various foreign markets.

In 2017, our crude oil exports decreased in volume by 1.7%, from 1,194.3 thousand barrels per day in 2016 to 1,174.0 thousand barrels per day in 2017. Natural gas imports decreased by 8.7% in 2017, from 1,933.9 million cubic feet per day in 2016 to 1,766.0 million cubic feet per day in 2017. In 2017, exports of petrochemical products decreased 51.6%, from 124.7 thousand metric tons in 2016 to 60.4 thousand metric tons in 2017, while imports of petrochemical products increased 19.6%, from 278.2 thousand metric tons in 2016 to 332.8 thousand metric tons in 2017. In 2017, exports of other petroleum products decreased 14.8%, from 185.5 thousand barrels per day in 2016 to 158.0 thousand barrels per day in 2017, while imports of other petroleum products and liquefied petroleum gas increased 17.0%, from 800.4 thousand barrels per day in 2016 to 936.2 thousand barrels per day in 2017. As a major supplier of crude oil to the United States, our international trading segment’s crude oil exports to the United States totaled U.S. $10.5 billion in 2017, an increase of U.S. $3.0 billion from 2016.

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Infrastructure of PEMEX

Exploration and Production

Following our 2015 corporate reorganization, certain business units and assets that were operated by our exploration and production segment were transferred to our drilling and services segment upon the formation of Pemex Drilling and Services on August 1, 2015. For the year ended December 31, 2015, we have not presented separately the operating results of our drilling and services segment in this Item 4 and, accordingly, the results of our exploration and production segment include the results of that segment for this period. Operating results for both the exploration and production and drilling and services segments are presented separately for periods beginning January 1, 2016. For a detailed description of the financial results of each segment, see our consolidated financial statements included herein.

Exploration and Drilling

We seek to identify new oil reservoirs through our exploration program in order to increase the future replacement rate of proved reserves. From 1990 to 2017, we completed 13,229 exploration and development wells. During 2017, our average success rate for exploratory wells was 62.5%, an 18.5% increase as compared to 2016 and our average success rate for development wells was 92.9%, an 8.1% increase as compared to 2016. From 2013 to 2017, we discovered 15 new crude oil fields and 7 new natural gas fields, bringing the total number of our crude oil and natural gas producing fields to 397 at the end of 2017.

Our 2017 exploration program was comprised of exploration in both onshore and offshore regions, including the deep waters of the Gulf of Mexico. These exploratory activities yielded 246 million barrels of oil equivalent of proved reserves resulting from the discovery of one oil producing field and two gas and condensate

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producing fields. We continued our main seismic data acquisition activities, in particular, those related to three-dimensional seismic data. In 2017, we acquired 14,276 square kilometers of three-dimensional seismic data in deep and shallow waters.

The following table summarizes our drilling activity for the five years ended December 31, 2017, all of which occurred in Mexican territory.

	Year ended December 31,
	2013		2014		2015		2016			2017
Wells initiated(1)		705		474		274		93			70
Exploratory wells initiated(1)		40		20		22		23			22
Development wells initiated(1)		665		454		252		70			48
Wells drilled(2)		817		535		312		149			79
Exploratory wells		38		24		26		21			24
Productive exploratory wells(3)		23		8		13		6			10
Dry exploratory wells		15		16		13		15			14
Success rate %		61		33		50		29			62.5
Development wells		779		511		286		128			55
Productive development wells		747		484		266		110			50
Dry development wells		32		26		20		18			4
Success rate %(4)		96		95		93		86			92.9
Producing wells (annual averages)		9,836		9,558		9,363		8,750			6,699
Marine region		559		581		544		539			443
Southern region		1,340		1,420		1,403		1,244			931
Northern region		7,937		7,557		7,416		6,966			5,325
Producing wells (at year end)(5)		9,379		9,077		8,826		8,073			8,208
Crude oil		6,164		5,598		5,374		4,912			4,956
Natural gas		3,215		3,479		3,452		3,161			3,238
Producing fields		454		428		434		405			398
Marine region		42		45		41		43			43
Southern region		102		97		97		88			91
Northern region		310		286		296		274			264
Drilling rigs		139		136		113		110			83
Kilometers drilled		1,627		1,413		815		330			280
Average depth by well (meters)		2,710		2,738		3,038		3,655			3,639
Discovered fields(6)		10		2		6		1			3
Crude oil		5		—		6		1			1
Natural gas		5		2		—		—			2
Crude oil and natural gas output by well (barrels of oil equivalent per day)		371		370		349		348			291
Total developed acreage (km2)(7)		8,706		8,339		8,654		7,017	(8)		6,886	(8)
Total undeveloped acreage (km2)(7)		977		1,278		1,000		712	(8)		620	(8)

Note: Numbers may not total due to rounding.

(1) “Wells initiated” refers to the number of wells the drilling of which commenced in a given year, regardless of when the well was or will be completed.

(2) “Wells drilled” refers to the number of wells the drilling of which was completed in a given year, regardless of when the drilling of the well commenced.

(3) Excludes non-commercial productive wells.

(4) Excludes injector wells.

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(5) For the years ended December 31, 2013, 2014 and 2015, all productive wells, and all other wells referred to in this table, are “net,” because we did not grant others any fractional working interests in any wells that we owned no acquired any fractional working interest in wells owned by others. Figures for the years ended December 31, 2016 and 2017 include fractional interests obtained pursuant to joint ventures and associations.

(6) Includes only fields with proved reserves.

(7) For the years ended December 31, 2013, 2014 and 2015, all acreage is net because we neither granted others fractional interests nor entered into other types of production sharing arrangements. Figures for the years ended December 31, 2016 and 2017 include fractional interests obtained pursuant to joint ventures and associations.

(8) These values relate only to our current assignments.

Source: Pemex Exploration and Production.

Extensions and Discoveries

During 2017, our exploratory activity in the shallow waters of the Gulf of Mexico and onshore regions resulted in new discoveries of light crude oil in the offshore Suuk field in June 2017 and gas and condensate discoveries in the onshore Valeriana and Ixachi fields in August and November of 2017, respectively. These discoveries led to the incorporation of approximately 246 million barrels of oil equivalent in three fields.

On November 3, 2017, we announced the discovery of onshore light crude oil and gas reservoirs at the Ixachi-1 well in the state of Veracruz, Mexico, which we believe may contain over 1.5 billion barrels of oil equivalent. We believe that this discovery represents our largest onshore discovery in 15 years and that production can be accelerated due to the proximity of the reservoirs to existing infrastructure and to the Sistema Nacional de Gasoductos (National Gas Pipeline System).

Reserves

Under the Mexican Constitution, all oil and other hydrocarbon reserves located in the subsoil of Mexico are owned by the Mexican nation and not by us. As of December 31, 2014, Pemex-Exploration and Production was assigned rights through Round Zero corresponding to areas that together contained 95.2% of Mexico’s total proved reserves. Pemex Exploration and Production, as the successor to Pemex-Exploration and Production, has the right to extract, but not own, these reserves, and to sell the resulting production. As of the date of this report, the exploration and development activities of Petróleos Mexicanos and the subsidiary entities are limited to reserves located in Mexico.

Proved oil and natural gas reserves are those estimated quantities of crude oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be economically producible from a given date forward, from known reservoirs and under existing economic conditions, operating methods and government regulations.

Proved reserves estimates as of December 31, 2017 were prepared by our exploration and production segment and were reviewed by the Independent Engineering Firms (as defined below), which audit its estimates of our oil and gas reserves. In addition, pursuant to the Reglamiento de la Ley de Hidrocarburos (Regulations under the Hydrocarbons Law), the CNH reviewed the proved reserves reports estimates as of December 31, 2017 and approved them on March 28, 2018. See “Item 3—Key Information—Risk Factors—Risk Factors Related to our Relationship with the Mexican Government— Information on Mexico’s hydrocarbon reserves is based on estimates, which are uncertain and subject to revisions.”

We estimate reserves based on generally accepted petroleum engineering and evaluation methods and procedures, which are based primarily on applicable SEC regulations and, as necessary, the Society of Petroleum Engineers’ (which we refer to as the SPE) publication entitled Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information, dated February 19, 2007 and other SPE publications, including the SPE’s publication entitled Petroleum Resources Management System, as well as other technical sources, including Estimation and Classification of Reserves of Crude Oil, Natural Gas, and Condensate, by Chapman

31

Cronquist, and Determination of Oil and Gas Reserves, Petroleum Society Monograph Number 1, published by the Canadian Institute of Mining and Metallurgy & Petroleum. The choice of method or combination of methods employed in the analysis of each reservoir is determined by:

• experience in the area;

• stage of development;

• quality and completeness of basic data; and

• production and pressure histories.

Reserves data set forth herein represent only estimates. Reserves valuation is a subjective process of estimating underground accumulations of crude oil and natural gas that cannot be measured in an exact manner. The accuracy of any reserves estimate depends on the quality of available data, engineering and geological interpretation and professional judgment. As a result, estimates of different engineers may vary. In addition, the results of drilling, testing and producing subsequent to the date of an estimate may lead to the revision of an estimate.

During 2017, we did not record any material increase in our proved oil and gas reserves as a result of the use of new technologies.

In order to ensure the reliability of our reserves estimation efforts, we have undertaken the internal certification of our estimates of reserves since 1996. We have established certain internal controls in connection with the preparation of our proved reserves estimates. Initially, teams of geoscientists from our exploration and production business units (with each of these units covering several projects) prepare the reserves estimates, using distinct estimation processes for valuations relating to new discoveries and developed fields, respectively. Subsequently, the regional reserves offices collect these reserves estimates from the units and request that the Gerencia de Recursos y Certificación de Reservas (Office of Resources and Certification of Reserves), the central hydrocarbon reserves management body of Pemex Exploration and Production, review and certify such valuations and the booking of the related reserves. This internal certification process is undertaken in accordance with internal guidelines for estimating and classifying proved reserves, which are based on the SEC’s rules and definitions. The Office of Resources and Certification of Reserves, which additionally oversees and conducts an internal audit of the process described above, consists entirely of professionals with geological, geophysical, petrophysical and reservoir engineering backgrounds. Additionally, the engineers who participate in our reserves estimation process are experienced in: reservoir numerical simulation; well drilling and completion; pressure, volume and temperature (PVT) and analytical tools used in forecasting the performance of the various elements comprising the production system; and design strategies in petroleum field development. Furthermore, all of our personnel have been certified by the Secretaría de Educación Pública (Ministry of Public Education), most have earned master’s degrees in areas of study such as petroleum engineering, geology and geophysical engineering and they possess an average of over fifteen years of professional experience.

In addition to this internal review process, our exploration and production segment’s final reserves estimates are audited by independent engineering firms. Three independent engineering firms audited our estimates of proved reserves as of December 31, 2017: Netherland Sewell; DeGolyer and MacNaughton; and Ryder Scott (we refer to these firms together as the Independent Engineering Firms). The reserves estimates reviewed by the Independent Engineering Firms totaled 97.0% of our estimated proved reserves. The remaining 3.0% of our estimated proved reserves consisted of reserves located in certain areas in which third parties provide us with drilling services. Netherland Sewell audited the reserves in the Aceite Terciario de Golfo, Poza Rica-Altamira and the Litoral de Tabasco business units. DeGolyer and MacNaughton audited reserves in the Burgos and Veracruz business units and Ryder Scott audited the reserves in the Bellota-Jujo, Cinco Presidentes, Macuspana-Muspac, Samaria-Luna, Abkatún-Pol-Chuc, Cantarell and Ku-Maloob-Zaap business units. The audits conducted by the Independent Engineering Firms consisted primarily of: (1) analysis of historical static and dynamic reservoir data that we have provided; (2) construction or updating of the Independent Engineering Firms’ own

32

static and dynamic reservoir characterization models of some of our fields; (3) economic analysis of fields; and (4) review of our production forecasts and reserves estimates.

Since reserves estimates are, by definition, only estimates, they cannot be reviewed for the purpose of verifying exactness. Instead, the Independent Engineering Firms conducted a detailed review of our reserves estimates so that they could express an opinion as to whether, in the aggregate, the reserves estimates we furnished were reasonable and had been estimated and presented in conformity with generally accepted petroleum engineering and evaluation methods and procedures.

All questions, including any suggested modifications to proved reserves estimates, that arose during the Independent Engineering Firms’ review process were resolved by our exploration and production segment to the satisfaction of the Independent Engineering Firms. The Independent Engineering Firms have concluded that our estimated total proved oil and natural gas reserve volumes set forth in this report are, in the aggregate, reasonable and have been prepared in accordance with Rule 4-10(a) of Regulation S-X of the SEC, as amended (which we refer to as Rule 4-10(a)), are consistent with international reserves reporting practice and are in accordance with the revised oil and gas reserves disclosure provisions of ASC Topic 932.

Our total proved developed and undeveloped reserves of crude oil, condensates and liquefiable hydrocarbons recoverable from field processing plants decreased by 11.0% in 2017, from 7,219 million barrels at December 31, 2016 to 6,427 million barrels at December 31, 2017. Our proved developed reserves of crude oil, condensates and liquefiable hydrocarbons recoverable from processing plants decreased by 14.7% in 2017, from 4,886 million barrels at December 31, 2016 to 4,166 million barrels at December 31, 2017. These decreases were principally due to a decrease in oil production in 2017, a decrease in field development and, following bidding rounds conducted by the Mexican Government, the transfer to third parties of rights to certain fields included in our 2016 reserves. The amount of crude oil, condensate and liquefiable hydrocarbon reserves added in 2017 was insufficient to offset the level of production in 2017, which amounted to 805 million barrels of crude oil, condensates and liquefiable hydrocarbons.

Our total proved developed and undeveloped dry gas reserves decreased by 5.6% in 2017, from 6,984 billion cubic feet at December 31, 2016 to 6,593 billion cubic feet at December 31, 2017. Our proved developed dry gas reserves decreased by 10.8% in 2017, from 4,513 billion cubic feet at December 31, 2016 to 4,026 billion cubic feet at December 31, 2017. These decreases were principally due to a decrease in oil production in 2017, a decrease in field development, the natural decline of fields and, following bidding rounds conducted by the Mexican Government, the transfer to third parties of rights to certain fields included in our 2016 reserves. The amount of dry gas reserves added in 2017 was insufficient to offset the level of production in 2017, which amounted to 999 billion cubic feet of dry gas. Our proved undeveloped dry gas reserves increased by 3.9% in 2017, from 2,471 billion cubic feet at December 31, 2016 to 2,567 billion cubic feet at December 31, 2017.

During 2017, our exploratory activity in the shallow waters of the Gulf of Mexico and onshore regions resulted in new discoveries of light crude oil in the offshore Suuk field in June 2017 and gas and condensate discoveries in the onshore Valeriana and Ixachi fields in August and November of 2017, respectively. These discoveries led to the incorporation of approximately 246 million barrels of oil equivalent in three fields.

In 2017, our proved reserves increased by 174.2 million barrels of oil equivalent due to reclassifications, development, revisions and discoveries.

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The following three tables of crude oil and dry gas reserves set forth our estimates of our proved reserves determined in accordance with Rule 4-10(a).

Summary of Oil and Gas⁽¹⁾ Proved Reserves as of December 31, 2017 Based on Average Fiscal Year Prices

	Crude Oil and Condensates(2)		Dry Gas(3)
	(in millions of barrels)		(in billions of cubic feet)
Proved developed and undeveloped reserves
Proved developed reserves		4,166		4,026
Proved undeveloped reserves		2,261		2,567
Total proved reserves		6,427		6,593

Note: Numbers may not total due to rounding

(1) We do not currently produce synthetic oil or synthetic gas, or other natural resources from which synthetic oil or synthetic gas can be produced.

(2) Crude oil and condensate reserves include the fraction of liquefiable hydrocarbons recoverable in natural gas processing plants located at fields.

(3) Reserve volumes reported in this table are volumes of dry gas, although natural gas production reported in other tables refers to sour wet gas. There is a shrinkage in volume when natural gas liquids and impurities are extracted to obtain dry gas. Therefore, reported natural gas volumes are greater than dry gas volumes.

Source: Pemex Exploration and Production.

Crude Oil and Condensate Reserves

(including natural gas liquids)⁽¹⁾

	2013			2014			2015			2016			2017
Proved developed and undeveloped reserves	(in millions of barrels)
At January 1		11,424			11,079			10,292			7,977			7,219
Revisions(2)		630			95			(1,491	)		189			(95	)
Extensions and discoveries		62			119			111			(55	)		147
Production		(1,037	)		(1,001	)		(935	)		(891	)		(805	)
Farm-outs and transfer of fields due to CNH bidding process		—			—			—			—			(38	)
At December 31		11,079			10,292			7,977			7,219			6,427
Proved developed reserves at December 31		7,360			7,141			5,725			4,886			4,166
Proved undeveloped reserves at December 31		3,719			3,151			2,252			2,333			2,261

Note: Numbers may not total due to rounding.

(1) Crude oil and condensate reserves include the fraction of liquefiable hydrocarbons recoverable in natural gas processing plants located at fields.

(2) Revisions include positive and negative changes due to new data from well drilling, revisions made when actual reservoir performance differs from expected performance and the effect of changes in hydrocarbon prices.

Source: Pemex Exploration and Production.

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Dry Gas Reserves

	2013			2014			2015			2016			2017
Proved developed and undeveloped reserves	(in billions of cubic feet)
At January 1		12,713			12,273			10,859			8,610			6,984
Revisions(1)		1,010			4			(955	)		(183	)		169
Extensions and discoveries		89			93			47			(308	)		468
Production(2)		(1,539	)		(1,511	)		(1,341	)		1,134			(999	)
Farm-outs and transfer of fields due to CNH bidding process		—			—			—			—			(29	)
At December 31		12,273			10,859			8,610			6,984			6,593
Proved developed reserves at December 31		7,461			6,740			6,012			4,513			4,026
Proved undeveloped reserves at December 31		4,811			4,119			2,598			2,471			2,567

Note: Numbers may not total due to rounding.

(1) Revisions include positive and negative changes due to new data from well drilling, revisions made when actual reservoir performance differs from expected performance and the effect of changes in hydrocarbon prices.

(2) Production refers here to dry gas, although natural gas production reported in other tables refers to sour wet gas. There is a shrinkage in volume when natural gas liquids and impurities are extracted to obtain dry gas. Therefore, reported natural gas volumes are greater than dry gas volumes.

Source: Pemex Exploration and Production.

The following table sets forth, as of December 31, 2017, the volumes of proved developed and undeveloped reserves, the number of producing wells and the number of proved undeveloped locations for the fields that contained 95.1% of our proved reserves.

	Reserves
Field	Proved(1)		Developed(1)		Undeveloped(1)		Number of Producing Wells		Number of Undeveloped Locations(2)
	(in millions of barrels of oil equivalent)
Ku-Maloob-Zaap		2,225.1		1,845.6		379.5		168		28
Akal		707.5		707.5		—		79		—
Ayatsil		624.5		202.7		421.8		9		11
Aceite Terciario del Golfo(3)		620.1		125.5		494.6		1,984		3,204
Onel		200.1		140.8		59.3		8		7
Jujo-Tecominoacán		189.7		97.8		91.9		34		18
Antonio J. Bermudez(4)		184.1		118.5		65.6		230		25
Xikin		148.5		—		148.5		—		5
Xanab		114.9		90.7		24.2		14		4
Balam		114.4		65.7		48.7		9		4
Ixachi		97.9		21.3		76.6		—		6
Xux		95.8		74.1		21.7		13		3
Ek		82.6		16.6		66.0		11		7
Santuario		67.7		20.2		47.6		30		33
Lakach		63.5		—		63.5		—		3
Tekel		59.9		—		59.9		—		4
Arenque		57.6		23.9		33.7		14		9
Pokche		56.9		—		56.9		—		4
Homol		55.8		42.8		13.0		11		—
Tamaulipas Constituciones		55.6		23.6		32.0		242		136
Tsimín		52.7		52.7		—		15		—

35

	Reserves
Field	Proved(1)		Developed(1)		Undeveloped(1)		Number of Producing Wells		Number of Undeveloped Locations(2)
	(in millions of barrels of oil equivalent)
Teotleco		49.1		25.6		23.6		12		3
Kab		48.8		14.7		34.1		5		4
Tizón		42.6		41.7		0.9		11		0
Utsil		42.1		0.0		42.1		—		4
Ayín		39.0		0.0		39.0		—		3
Kambesah		36.6		36.6		0.0		4		0
Sihil		36.5		36.5		0.0		13		0
Cárdenas		36.0		24.3		11.7		8		4
Ébano Chapacao		35.9		27.2		8.7		175		88
Costero		35.3		35.3		0.0		12		0
Suuk		35.0		0.0		35.0		—		3
Giraldas		33.1		24.6		8.5		9		1
Poza Rica		32.8		26.1		6.7		156		24
May		31.7		31.7		0.0		12		0
Ixtal		31.1		31.1		0.0		10		0
Ogarrio		31.0		30.1		1.0		77		2
Puerto Ceiba		30.8		19.5		11.2		13		5
Kuil		29.4		13.4		16.0		9		4
Chinchorro		27.3		20.7		6.7		5		2
Yaxché		26.6		7.4		19.2		6		5
Gasífero		26.3		21.7		4.6		23		7
Kax		26.3		26.3		0.0		2		0
Nejo		24.4		21.8		2.6		198		23
Chuc		23.5		20.4		3.1		11		0
Bellota		22.8		16.7		6.0		5		2
Rabasa		22.4		21.1		1.3		42		1
Terra		22.1		9.7		12.4		11		3
Lum		21.6		17.7		3.9		3		3
Sen		21.1		14.5		6.6		11		1
Valeriana		20.9		0.0		20.9		—		1
Madrefil		20.8		16.7		4.1		6		1
Etkal		20.2		3.7		16.5		1		2
Cuervito		19.9		7.6		12.2		84		52
Eltreinta		19.6		12.2		7.5		11		8
Jaatsul		19.1		0.0		19.1		—		3
Mora		17.9		9.4		8.5		4		4
Ixtoc		17.9		17.9		0.0		10		0
Bolontikú		17.8		17.8		0.0		5		0
Edén-Jolote		17.3		12.4		4.9		7		2
Tupilco		17.1		15.2		1.8		25		1
Sunuapa		16.1		13.4		2.7		4		2
Caparroso-Pijije-Escuintle		15.5		11.8		3.8		16		1
Cinco Presidentes		15.5		13.9		1.6		31		1
Los Soldados		15.4		14.1		1.3		21		3
Paredón		15.1		15.1		0.0		3		0
Cuitláhuac		15.1		11.2		3.9		185		10
Cacalilao		14.0		6.6		7.4		88		99

36

	Reserves
Field	Proved(1)			Developed(1)			Undeveloped(1)			Number of Producing Wells		Number of Undeveloped Locations(2)
	(in millions of barrels of oil equivalent)
Esah		12.5			—			12.5			—		1
Sini		12.3			8.3			4.0			7		1
Och		12.3			12.3			—			5		—
Tintal		12.3			8.9			3.4			7		7
Manik		12.0			12.0			—			3		—
Bedel		11.5			5.1			6.4			6		7
Nohoch		11.4			11.4			—			7		—
Santa Anita		11.2			7.4			3.8			60		7
Takín		10.9			10.9			—			4		—
Pánuco		10.8			3.5			7.3			51		121
Cauchy		10.7			10.7			—			18		—
San Ramón		10.5			9.1			1.4			39		3
Sinán		10.4			10.4			—			6		—
Ayocote		10.2			7.9			2.4			13		1
Taratunich		10.1			10.1			—			7		—
Guaricho		10.1			9.6			0.5			15		1
Blasillo		9.1			6.9			2.2			22		6
Bacab		9.1			9.1			—			6		—
Uech		9.1			9.1			—			2		—
Total		7,317.8			4,648.1			2,670.0			4,493		4,048
Our proved reserves		7,694.7			4,940.3			2,754.4
Percentage		95.1	%		94.1	%		96.9	%

Note: Numbers may not total due to rounding.

(1) Proved reserves, developed reserves and undeveloped reserves are expressed in millions of barrels of oil equivalent. To convert dry gas to barrels of oil equivalent, a factor of 5.201 thousand cubic feet of dry gas per barrel of oil equivalent is used.

(2) Undeveloped Locations refers to the number of geographic sites or locations where a well will be drilled to produce undeveloped proved reserves.

(3) Includes extraction assignments and temporary assignments.

(4) Includes the Cunduacán, Iride, Oxiacaque, Platanal and Samaria fields.

Source: Pemex Exploration and Production.

Our reserve-replacement ratio, or RRR, for a given period is calculated by dividing the sum of proved reserves additions due to discoveries, developments, delineations and revisions by that period’s total production. During 2017, we obtained 174.2 million barrels of oil equivalent of proved reserves, which represents an RRR of 17.5%, as compared to our RRR of 4.0% in 2016. We expect continued improvements in our RRR in subsequent years.

Our reserves production ratio, which is presented in terms of years, is calculated by dividing the estimated remaining reserves at the end of the relevant year by the total production of hydrocarbons for that year. As of December 31, 2017, this ratio stayed constant with 2016 levels and was equal to 7.7 years for proved reserves. For more information, see Note 29 to our consolidated financial statements included herein.

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Sales Prices and Production Costs

The following table sets forth our average sales price per unit of oil and gas produced and our average production cost per unit of production, in the aggregate and for each field containing 10% or more of our proved reserves.

Unit Sales Prices and Production Costs⁽¹⁾

	Ku-Maloob- Zaap		Akal		Other Fields		All Fields
Year ended December 31, 2017		(in U.S. dollars)
Average sales prices
Crude oil, per barrel	U.S. $	41.70	U.S. $	48.75	U.S. $	52.90	U.S. $	48.71
Natural gas, per thousand cubic feet	U.S. $	5.07	U.S. $	4.25	U.S. $	4.12	U.S. $	4.32
Average production costs, per barrel of oil equivalent	U.S. $	7.53	U.S. $	23.25	U.S. $	11.53	U.S. $	10.90
Year ended December 31, 2016
Average sales prices
Crude oil, per barrel	U.S. $	30.11	U.S. $	36.67	U.S. $	40.21	U.S. $	36.55
Natural gas, per thousand cubic feet	U.S. $	3.40	U.S. $	2.86	U.S. $	3.16	U.S. $	3.01
Average production costs, per barrel of oil equivalent	U.S. $	5.34	U.S. $	16.53	U.S. $	8.08	U.S. $	7.78
Year ended December 31, 2015
Average sales prices
Crude oil, per barrel	U.S. $	41.21	U.S. $	47.79	U.S. $	51.51	U.S. $	48.22
Natural gas, per thousand cubic feet	U.S. $	4.59	U.S. $	3.59	U.S. $	3.79	U.S. $	3.78
Average production costs, per barrel of oil equivalent	U.S. $	6.93	U.S. $	15.97	U.S. $	9.69	U.S. $	9.40

(1) Average of sales prices as of the last day of each month of the year.

Source: Pemex Exploration and Production.

In 2017, our average production cost was U.S. $10.90 per barrel of oil equivalent, and represented an increase of 40.1%, as compared to our average production cost of U.S. $7.78 per barrel in 2016. This increase resulted primarily from an increase in expenses for the maintenance of wells, equipment and production facilities and payments of non-income related taxes and duties.

We calculate and disclose our production costs pursuant to international practices, which are based on U.S. GAAP under ASC Topic 932. In accordance with ASC Topic 932, the production cost per barrel of oil equivalent is calculated by dividing total production expenses (in U.S. dollars) by total production of oil and gas (in barrels of oil equivalent) for the relevant period.

Our total production cost consists of all direct and indirect costs incurred to produce crude oil and gas, including costs associated with the operation and maintenance of wells and related equipment and facilities. In addition, it includes costs of labor to operate the wells and facilities, the costs of materials, supplies and fuel consumed, including gas used for gas lifting, nitrogen and other chemicals, repair and non-capitalized maintenance costs, and other costs, such as fees for general services, a labor fund for active personnel, corporate services, indirect overhead and applicable taxes and duties. However, it excludes non-cash expenses such as amortization of capitalized well expenses, the depreciation of fixed assets, expenses associated with the distribution and handling of oil and gas and other expenses that are related to exploration and drilling activities.

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Crude Oil and Natural Gas Production

In 2017, we produced an average of 1,948.3 thousand barrels per day of crude oil, 9.5% less than our average production in 2016 of 2,153.5 thousand barrels per day of crude oil. The decrease in 2017 resulted primarily from the decrease of production in the Cantarell, Crudo Ligero Marino, El Golpe-Puerto Ceiba, Bellota-Chinchorro, Complejo Antonio J. Bermúdez, Cactus Sitio Grande, Ixtal-Manik, Chuc, Costero Terrestre, and Tsimín-Xux projects. Accordingly, our average production of heavy crude oil decreased by 53.6 thousand barrels per day, or 4.9% less than the average daily production in 2016, primarily due to a decrease in our drilling activities, the natural decline in field production, an increase in fractional flow water production and an increase in the gas production cap of reservoirs, particularly for reservoirs past the saturation stage. In 2017, the average production of light crude oil decreased by 96.3 thousand barrels per day, or 12.3%, as compared to 2016. This decrease occurred mainly due to a natural decline in production in the Chuhuk, Caan, and Ixtal fields of the Abkatún-Pol-Chuc business unit; the Tsimín, Sinán, Bolontikú, and Yaxché fields of the Litoral de Tabasco business unit; the Costero, Sitio Grande, Teotleco fields of the Macuspana-Muspac business unit and the Samaria, Íride, Cunduacán and Sini fields of the Samaria-Luna business unit.

Crude oil can be classified by its sulfur content. “Sour” or heavy crude oil contains 3.4% or greater sulfur content by weight and “sweet” or light crude oil contains less than 1.0% sulfur content by weight. Most of our production is classified as sour or heavy crude oil.

Our exploration and production segment primarily produces four types of crude oil:

• Altamira, a heavy crude oil;

• Maya, a heavy crude oil;

• Isthmus, a light crude oil; and

• Olmeca, an extra-light crude oil.

Most of our production consists of Isthmus and Maya crude oil. In 2017, 53.8% of our total production of crude oil consisted of heavy crude oil and 46.2% consisted of light and extra-light crude oil. The Marine regions yield mostly heavy crude oil (61.7% of these regions’ production in 2017), although significant volumes of light crude oil are also produced there (38.2% of these regions’ production in 2017). The Southern region yields mainly light and extra-light crude oil (together, 93.7% of this region’s production in 2017), and the Northern region yields both light and extra-light crude oil (44.7% of this region’s production in 2017) and heavy crude oil (55.3% of this region’s production in 2017).

The most productive crude oil and natural gas fields in the Gulf of Mexico are located in the Ku-Maloob-Zaap, Litoral de Tabasco, Abkatún-Pol-Chuc and Cantarell business units in the Marine regions and the Sarmaria Luna and Bellota-Jujo business units in the Southern region. In particular, the Ku-Maloob-Zaap business unit was the most important crude oil producer in 2017, producing an average of 858.0 thousand barrels of crude oil per day in 2017, or 44.0% of our total crude oil production for the year, and 552.3 million cubic feet per day of natural gas, or 10.9% of our total natural gas production for the year. Our second most important crude oil producer was Litoral de Tabasco which produced an average of 345.8 thousand barrels of crude oil per day in 2017, or 17.7% of our total crude oil production for the year, and an average of 882.3 million cubic feet per day of natural gas, or 17.4 % of our total natural gas production for the year.

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The following table sets forth our annual crude oil production rates by type of oil for the five years ended December 31, 2017.

Crude Oil Production

											2017 vs. 2016
	2013		2014		2015		2016		2017
	(in thousands of barrels per day)										(%)
Marine regions
Heavy crude oil		1,258.3		1,160.1		1,054.9		1,018.3		978.0		(4.0	)
Light crude oil(1)		638.1		691.3		705.4		682.7		605.6		(11.3	)
Total		1,896.4		1,851.4		1,760.3		1,700.9		1,583.6		(6.9	)
Southern region
Heavy crude oil		26.5		35.0		31.7		22.3		16.9		(24.2	)
Light crude oil(1)		454.3		417.4		362.1		321.8		249.8		(22.4	)
Total		480.8		452.4		393.8		344.1		266.7		(22.5	)
Northern region
Heavy crude oil		80.2		70.4		65.7		62.0		54.2		(12.7	)
Light crude oil(1)		64.7		54.6		47.0		46.5		43.8		(5.8	)
Total		144.9		125.0		112.7		108.5		97.9		(9.8	)
Total heavy crude oil		1,365.1		1,265.5		1,152.3		1,102.6		1,049.0		(4.9	)
Total light crude oil(1)		1,157.1		1,163.3		1,114.5		1,050.9		899.2		(14.4	)
Total crude oil		2,522.1		2,428.8		2,266.8		2,153.5		1,948.3		(9.5	)

Note: Numbers may not total due to rounding.

(1) Includes extra-light crude oil.

Source: Pemex Exploration and Production.

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The following table sets forth our annual crude oil production by region and business unit for the five years ended December 31, 2017.

Crude Oil Production

											2017 vs. 2016
	2013		2014		2015		2016		2017
	(in thousands of barrels per day)										(%)
Marine regions
Ku-Maloob-Zaap		863.8		856.7		853.1		866.6		858.0		(1.0	)
Cantarell		439.8		374.9		273.4		215.8		176.0		(18.1	)
Litoral de Tabasco		299.2		320.4		347.2		359.9		345.8		(3.9	)
Abkatún-Pol-Chuc		293.6		299.3		286.7		258.7		203.2		(21.4	)
Total		1,896.4		1,851.4		1,760.3		1,700.9		1,583.6		(6.9	)
Southern region
Samaria-Luna		172.5		161.4		145.4		127.0		99.9		(21.4	)
Bellota-Jujo		134.3		124.8		101.7		90.3		72.4		(19.8	)
Cinco Presidentes		93.1		89.1		87.6		80.0		63.1		(21.0	)
Macuspana-Muspac		80.9		77.0		59.0		46.8		31.3		(33.1	)
Total		480.8		452.4		393.8		344.1		266.7		(22.5	)
Northern region
Aceite Terciario del Golfo		66.2		48.8		42.0		39.8		34.4		(13.5	)
Poza Rica-Altamira		61.5		59.8		58.7		53.9		48.2		(10.6	)
Burgos		8.0		5.0		—		—		—		—
Veracruz		9.3		11.4		12.1		14.8		15.3		3.5
Total		144.9		125.0		112.7		108.5		97.9		(9.7	)
Total crude oil		2,522.1		2,428.8		2,266.8		2,153.5		1,948.3		(9.5	)

Note: Numbers may not total due to rounding.

Source: Pemex Exploration and Production.

The Marine regions, which are comprised of the Northeastern Marine region and the Southwestern Marine region, are located on the continental shelf and its slope in the Gulf of Mexico. They cover a surface area of approximately 550,000 square kilometers, located entirely within Mexican territorial waters, along the coast of the states of Tabasco, Campeche, Yucatán, Quintana Roo and the southern coast of the state of Veracruz. In 2017, the average crude oil production from the 43 fields located in these regions was 1,583.6 thousand barrels per day.

The Southern region covers an area of approximately 392,000 square kilometers, including the states of Guerrero, Oaxaca, Chiapas, Tabasco, Yucatán, Quintana Roo, Campeche and Veracruz. In 2017, the average crude oil production from the 86 fields located in this region was 266.7 thousand barrels per day.

The Northern region, including its offshore area, is located on the continental shelf in the Gulf of Mexico along the coast of the state of Tamaulipas and the northern coast of the state of Veracruz. It covers an area of approximately 1.8 million square kilometers. Our production area in the onshore portion of this region is located in, among others, the states of Veracruz, Tamaulipas, Nuevo León, Coahuila, San Luis Potosí and Puebla; we also produce offshore on the continental shelf in the Gulf of Mexico. In 2017, the average crude oil and natural gas production in the Northern region totaled 98.0 thousand barrels of crude oil per day and 1,169.4 million cubic feet of natural gas per day, respectively, from the 263 oil and gas fields in this region.

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The following table sets forth our annual natural gas production by region and business unit for the five years ended December 31, 2017.

Natural Gas Production

											2017 vs. 2016
	2013		2014		2015		2016		2017
	(in millions of cubic feet per day)										(%)
Marine regions
Cantarell		1,007.1		1,120.9		1,277.1		1,184.9		1,133.4		(4.3	)
Litoral de Tabasco		747.6		842.6		993.5		950.0		882.3		(7.1	)
Abkatún-Pol-Chuc		579.4		553.4		455.9		390.5		319.5		(18.2	)
Ku-Maloob-Zaap		405.1		571.0		556.5		589.3		552.3		(6.3	)
Total		2,739.2		3,087.9		3,283.0		3,114.6		2,887.6		(7.3	)
Southern region
Samaria-Luna		606.3		583.1		500.3		498.7		426.9		(14.4	)
Macuspana-Muspac		515.1		490.5		455.3		382.2		291.6		(23.7	)
Bellota-Jujo		319.7		288.9		264.5		231.5		183.3		(20.8	)
Cinco Presidentes		129.4		152.8		160.1		137.7		109.1		(20.8	)
Total		1,570.5		1,515.4		1,380.1		1,250.0		1,011.0		(19.1	)
Northern region
Burgos		1,286.6		1,221.0		1,099.0		864.6		699.2		(19.1	)
Veracruz		494.5		455.3		392.2		322.8		263.5		(18.4	)
Aceite Terciario del
Golfo		167.0		149.5		145.2		142.5		118.5		(16.8	)
Poza Rica-Altamira		112.4		102.8		101.5		97.9		88.2		(9.9	)
Total		2,060.6		1,928.6		1,737.9		1,427.8		1,169.4		(18.1	)
Total natural gas		6,370.3		6,531.9		6,401.0		5,792.5		5,068.0		(12.5	)

Note: Numbers may not total due to rounding.

Source: Pemex Exploration and Production.

In 2017, the Marine regions produced 2,887.6 million cubic feet per day of natural gas, or 57.0% of our total natural gas production, a decrease of 7.3% as compared to the regions’ 2016 production of 3,114.6 million cubic feet per day. In 2017, the Southern region produced 1,011.0 million cubic feet per day of natural gas, or 19.9% of our total natural gas production, a decrease of 19.1% as compared to the region’s 2016 production of 1,250.0 million cubic feet per day. In 2017, the Northern region produced 1,169.4 million cubic feet per day of natural gas, or 23.1% of our total natural gas production, a decrease of 18.1% as compared to the region’s 2016 production of 1,427.8 million cubic feet per day.

Our average natural gas production decreased by 12.5% in 2017, from 5,792.5 million cubic feet per day in 2016 to 5,068.0 million cubic feet per day in 2017. Natural gas production associated with crude oil production accounted for 80.0% of total natural gas production in 2017, with the remainder of natural gas production consisting of extraction from fields holding natural gas reserves. As of December 31, 2017, 170 of our 394 gas producing fields, or 43%, produced non-associated gas. These non-associated gas fields accounted for 20.0% of all natural gas production in 2017.

Investments in Exploration and Production

In nominal peso terms, our capital expenditures for exploration and production were Ps. 85,491 million in 2017, as compared to Ps. 137,242 million in 2016, representing a decrease of 37.7% in nominal terms. Of our

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total capital expenditures, Ps. 20,454 million was directed to the Ku-Maloob-Zaap fields, Ps. 4,961 million was directed to the Tsimin-Xux project, Ps. 8,761 million was directed to the Chuc project, Ps. 3,119 million was directed to the Cantarell fields, Ps. 1,026 million was directed to the Crudo Ligero Marino project, Ps. 1,063 million was directed to the Ogarrio-Sánchez Magallanes project, Ps. 1,705 million was directed to the Delta del Gijalva fields, Ps. 1,306 million was directed to the Antonio J. Bermúdez fields, Ps. 606 million was used for development of the Burgos natural gas fields and Ps. 604 million was directed to the ATG project. During 2017, expenditures for these ten projects amounted to 28.3% of all our capital expenditures for exploration and production. The remaining 71.7% amounted to Ps. 61,282 million in nominal terms, which was directed to the 16 remaining projects, as well as to other exploratory projects, other development projects and administrative and technical support.

2018 Exploration and Production Capital Expenditures Budget

For 2018, our total capital expenditures budget is Ps. 81,765 million, as compared to Ps. 85,491 million of capital expenditures made in 2017, representing a decrease of 4.4%, largely due to our strategic focus on our most profitable projects. The 2018 budget includes all of the 24 ongoing strategic exploration and production projects, Ps. 18,266 million in other exploratory projects and Ps. 5 million in administrative and technical support. Approximately Ps. 57,092 million, or 69.8% of our 2018 capital expenditures budget, is to be allocated to projects relating to field development and pipelines. Approximately Ps. 24,674 million, or 30.2% of the total budget, will be allocated to exploration activities.

The 2018 exploration and production budget includes Ps. 17,071 million for investments in the Ku-Maloob-Zaap project, Ps. 5,086 million for the Integral Yaxché project, Ps. 13,311 million for the Chuc project, Ps. 1,077 million for the Tsimin-Xux project, Ps. 1,881 million for the Cantarell project, Ps. 675 million for the Delta del Grijalva project, Ps. 3,722 million for the Crudo Ligero Marino project, Ps. 1,522 million for the Antonio J. Bermúdez project, Ps. 1,375 million for the Ogarrio-Sánchez Magallanes project, Ps. 175 million for the Burgos project, Ps. 448 million for the Bellota Chinchorro project, and Ps. 35,423 million for the remaining projects, as well as for other exploratory and development projects and administrative and technical support.

Exploration and Production Investment Trends

In 2017, we invested Ps. 28,753 million in nominal terms, or 34% of the total capital expenditures of our exploration and production segment, in exploration activities, which represents an 11.3% decrease from the Ps. 32,441 million invested in exploration activities in 2016. In 2017, we invested Ps. 56,741 million in nominal terms, or 66.4% of our total capital expenditures in development activities, which represents a 45.8% decrease from the Ps. 104,801 million invested in development activities in 2016.

In 2018, we have budgeted Ps. 24,674 million, or 30.2% of total capital expenditures, for exploration activities of our exploration and production segment, which represents an 18.9% decrease in nominal terms from the amount invested in exploration activities in 2017. For development activities in 2018, we have budgeted Ps. 57,092 million, or 70% of total capital expenditures, which represents a 0.6% increase in nominal terms from the amount that we invested in development activities in 2017.

Our projected exploration and development capital expenditures correspond to the areas assigned to us through Round Zero, which represent the areas in which we are exploring, operating or have an interest in developing based on our operational capabilities. The Ministry of Energy granted us the right to explore and develop these areas with the aim of maintaining our production levels in the short term, while providing us with sufficient exploration opportunities to increase our production in the future. Given that a significant number of exploration areas were reserved by the Mexican Government for future competitive bidding rounds, we intend to carry out our strategy of increasing production and improving our RRR over time by entering into strategic joint

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ventures with other oil and gas companies. Through these joint ventures, we hope to gain access to new technology and international best practices, while sharing the costs associated with security, occupational health and environmental protection and minimizing our operational risks. Over time, the allocation of our capital expenditures budget may change according to the results of subsequent bidding rounds in which we participate. See “—Exploration and Production—New Exploration and Production Contracts and Farm-Outs” below in this Item 4.

The capital expenditures of our exploration and production segment have constituted 75.0% or more of our total capital expenditures in each of the last three years. In 2018, the budgeted capital expenditures of our exploration and production segment constitute 72.2% of our total.

The following table sets forth our capital expenditures related to exploration and development during the three years ended December 31, 2017 and our estimated capital expenditures budget for exploration and development for 2018.

Exploration and Development Capital Expenditures

	Year ended December 31,(1)						Budget 2018(2)
	2015		2016		2017
	(in millions of nominal pesos)
Exploration		Ps.   31,146		Ps.   32,441		Ps. 28,753		Ps. 24,674
Development		120,398		104,801		56,738		57,092
Total		Ps. 151,544		Ps. 137,242		Ps. 85,491		Ps. 81,765

Note: Numbers may not total due to rounding.

(1) Amounts based on cash basis method of accounting.

(2) Budget presented to the Board of Directors of Petróleos Mexicanos on March 5, 2018.

Source: Pemex Exploration and Production

Investments and Production by Project

We conduct exploration, production and development activities in fields throughout Mexico. Our main projects are Ku-Maloob-Zaap, Tsimin-Xux, ATG, Cantarell, Crudo Ligero Marino, Burgos, Chuc, Antonio J. Bermúdez, Ogarrio-Sánchez Magallanes and Delta del Grijalva. These projects are described below.

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Exploration and Production’s Capital Expenditures

	Year ended December 31,(1)						Budget 2018(2)
	2015		2016		2017
	(in millions of pesos)(3)
Exploration and Production
Ku-Maloob-Zaap	Ps.	23,507	Ps.	25,468	Ps.	20,454	Ps.	17,071
Tsimin-Xux		13,950		13,802		4,961		1,077
Integral Yaxché		6,649		10,116		7,984		5,086
Chuc		10,037		10,024		8,761		13,311
Cantarell		11,217		8,179		3,119		1,881
Lakach		3,079		5,683		1,058		751
Crudo Ligero Marino		9,275		4,931		1,026		3,722
Ogarrio-Sánchez Magallanes		4,626		3,543		1,063		1,375
Delta del Grijalva		4,687		2,859		1,705		675
Ek-Balam		2,722		2,687		737		6,080
Antonio J. Bermúdez		5,352		2,562		1,306		1,522
Burgos		5,855		2,032		606		175
Bellota-Chinchorro		4,070		1,978		400		448
Ixtal-Manik		1,439		1,740		368		989
Cactus-Sitio Grande		2,671		1,555		463		559
Aceite Terciario del Golfo		2,817		1,487		604		478
El Golpe-Puerto Ceiba		2,605		1,375		286		189
Jujo-Tecominoacán		847		997		565		776
Veracruz Basin		1,538		884		671		1,941
Integral Poza Rica		438		521		173		160
Tamaulipas-Constituciones		459		501		101		79
Ayín-Alux		1,161		443		1		—
Costero Terrestre		321		380		120		92
Cuenca de Macuspana		476		368		117		73
Lankahuasa		—		22		11		—
Arenque		26		16		6		11
Other Exploratory Projects		31,146		32,410		26,235		18,266
Other Development Projects		17		172		2,341		4,974
Administrative and Technical Support		557		507		249		5
Total	Ps.	151,546	Ps.	137,242	Ps.	85,491	Ps.	81,765

Notes: Numbers may not total due to rounding.

(1) Amounts based on cash basis method of accounting.

(2) Budget presented to the Board of Directors of Petróleos Mexicanos on March 5, 2018.

(3) Figures are stated in nominal pesos.

Source: Petróleos Mexicanos.

Ku-Maloob-Zaap Project. The Ku-Maloob-Zaap project was our most important producer of heavy crude oil and plays an important part in the production of the Maya crude oil mix. It is the most important project in Mexico in terms of total proved hydrocarbon reserves and crude oil production. It is composed of the Ayatsil, Bacab, Lum, Ku Maloob, Tekel, Utsil and Zaap fields, and extends over an area of 305.7 square kilometers. As of December 31, 2017, there was a total of 265 wells completed, 186 of which were producing. The project produced an average of 858.0 thousand barrels of crude oil per day, 44.0% of our total production, and 552.3 million cubic feet of natural gas per day in 2017. As of December 31, 2017, cumulative production was 5.4 billion barrels of crude oil and 2.7 trillion cubic feet of natural gas. As of December 31, 2017, proved hydrocarbon reserves totaled 2.7 billion barrels of crude oil and 1.3 trillion cubic feet of natural gas. Total proved

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reserves were 3.0 billion barrels of oil equivalent, of which 2.1 billion barrels of oil equivalent were proved developed reserves.

In nominal peso terms, our exploration and production segment’s capital expenditures for this project were Ps. 23,507 million in 2015, Ps. 25,468 million in 2016 and Ps. 20,454 million in 2017. For 2018, we anticipate that our capital expenditures will be Ps. 17,071 million and that total accumulated capital expenditures for this project will reach approximately U.S. $360,884 million. In 2017, we paid approximately U.S. $38.3 million to acquire approximately 101.5 billion cubic feet of nitrogen for the pressure maintenance project in the fifth module of the Cantarell nitrogen cryogenic plant, which began operations in November 2006. In 2018, we expect to spend approximately U.S. $38.8 million to acquire approximately 109.5 billion cubic feet of nitrogen for injection into the Ku-Maloob-Zaap fields.

Tsimin-Xux Project. This project consists of the Tsimin and Xux fields, which include volatile oil and gas condensate reservoirs in the shallow waters of the Gulf of Mexico. The Tsimin field is located 62 kilometers from the Dos Bocas Marine Terminal in Paraíso, Tabasco, while the Xux field is located on the continental shelf of the Gulf of Mexico, approximately ten kilometers off the coast of Tabasco. During 2017, one new well was completed at the Xux field. During 2017, average daily production at the Tsimin-Xux project totaled 88.7 thousand barrels of crude oil and 497.3 million cubic feet of natural gas. During 2017, the sales prices of the light and extra-light crude oil produced at this field averaged approximately U.S. $59.25 per barrel, making this one of our most important projects in terms of revenue generation.

As of December 31, 2017, cumulative production totaled 0.1 billion barrels of crude oil and 0.8 trillion cubic feet of natural gas. Proved oil and gas reserves totaled 67.4 million barrels of crude oil and 368.0 billion cubic feet of natural gas. Total proved reserves were 148.6 million barrels of oil equivalent, of which 126.8 million barrels of oil equivalent were proved developed reserves.

In nominal peso terms, our exploration and production segment’s capital expenditures for the Tsimin-Xux project were Ps. 4,961 million in 2017. In 2018, we expect capital expenditures for this project to total Ps. 1,077 million and that by the end of 2018 our total accumulated capital expenditures for this project will reach approximately U.S. $130.0 million.

Chuc Project. The Chuc project is the second largest producer of light crude oil in the Southwestern Marine region, and includes the operation and maintenance of the Pol-A facility and water injection complexes. In 2013, the Ministry of Finance and Public Credit approved the integration of the Caan project into the Chuc project. This project covers an area of 213 square kilometers and has been exploited by our exploration and production segment since 1981. The fields of this project are located on the continental shelf of the Gulf of Mexico, off the coast of the states of Tabasco and Campeche, at a depth of between the 20- and 100-meter isobaths, approximately 132 kilometers from the Dos Bocas Marine Terminal in Paraíso, Tabasco, and 79 kilometers northeast of Ciudad del Carmen, Campeche. The fields in the project include Abkatún, Batab, Caan, Ché, Chuc, Chuhuk, Etkal, Homol, Kanaab, Kuil, Onel, Pol, Taratunich and Tumut. In January 2007, the Pol and Batab projects were merged into the Chuc project. As of December 31, 2017, 117 wells had been completed, of which 79 were producing. During 2017, average production totaled 176.3 thousand barrels per day of crude oil and 276.6 million cubic feet per day of natural gas. As of December 31, 2017, cumulative production totaled 5.8 billion barrels of crude oil and 6.7 trillion cubic feet of natural gas. As of December 31, 2017, proved hydrocarbon reserves totaled 297.1 million barrels of oil and 518.7 billion cubic feet of natural gas, or 377.8 million barrels of oil equivalent. As of December 31, 2017, total proved developed reserves were 240.2 million barrels of oil equivalent.

In nominal peso terms, our exploration and production segment’s capital expenditures for the Chuc project were Ps. 10,037 million in 2015, Ps. 10,024 million in 2016 and Ps. 8,761 million in 2017. In 2018, we expect

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our capital expenditures to be Ps. 13,311 million and anticipate that our total accumulated capital expenditures for this project will reach approximately U.S. $143,581 million.

Cantarell Project. The Cantarell project is located on the continental shelf of the Gulf of Mexico. It consists of the Akal, Chac, Ixtoc, Kambesah, Kutz, Nohoch, Sihil and Takin fields, which extend over an area of 294.4 square kilometers. As of December 31, 2017, there was a total of 561 wells drilled in the Cantarell project, 125 of which were producing. During 2017, the Cantarell business unit, of which the Cantarell project is part, was the fourth most important producer of crude oil in Mexico, averaging 176.6 thousand barrels per day of crude oil. This was 18.1% less than 2016 production, which was 215.8 thousand barrels per day, as a result of the decline of crude oil reserves remaining in these fields. Natural gas production from the Cantarell business unit during 2017 averaged 1,133.4 million cubic feet per day. This was 4.3% less than the 2016 average natural gas production, which was 1,184.9 million cubic feet per day, due to the natural decline of field production and an increase in the fractional water flow of wells in highly fractured deposits.

As of December 31, 2017, cumulative production of the Cantarell project was 14.3 billion barrels of crude oil and 9.5 trillion cubic feet of natural gas. As of December 31, 2017, proved oil and gas reserves of the Cantarell project totaled 850.4 million barrels of crude oil and 941.8 billion cubic feet of natural gas. As of December 31, 2017, total proved reserves were 1,025.4 million barrels of oil equivalent, of which 910.7 million barrels were proved developed reserves.

The Akal field, which is the most important field in the Cantarell project, averaged 55.2 thousand barrels per day of crude oil production during 2017. This was 20.7% less than the average production in 2016, which was 69.5 thousand barrels per day.

In nominal peso terms, our exploration and production segment’s capital expenditures for the Cantarell project totaled Ps. 11,217 million in 2015, Ps. 8,179 million in 2016 and Ps. 3,119 million in 2017. For 2018, we budgeted Ps. 1,881 million for capital expenditures for the Cantarell project. By the end of 2018, we expect our total accumulated capital expenditures to be approximately U.S. $43,296 million for this project.

On October 10, 1997, we awarded a build-own-operate contract for a nitrogen cryogenic plant at the Cantarell project to a consortium formed by BOC Holdings, Linde, Marubeni, West Coast Energy and ICA Fluor Daniel. Under this contract, the consortium is responsible for the financing, design, construction and operation of the plant. The plant began operations in 2000 and cost approximately Ps. 10,131 million. Pursuant to the terms of the agreement, Pemex Exploration and Production has the right to acquire the nitrogen plant in the case of a default by the consortium. Pemex Exploration and Production has the obligation to acquire the nitrogen plant if it defaults under the contract. Under the terms of the contract, Pemex Exploration and Production committed to purchasing 1.2 billion cubic feet per day of nitrogen from the consortium and to continue to supply service through June 2027.

During 2017, we paid approximately U.S. $190.8 million under this contract for an approximate total volume of 398.6 billion cubic feet of nitrogen, which was injected into the Cantarell fields. In 2018, our exploration and production segment expects to pay approximately U.S. $205.7 million under this contract for an approximate total volume of 438.0 billion cubic feet of nitrogen to be injected into the fields.

Crudo Ligero Marino Project. In 2013, the Ministry of Finance and Public Credit approved the designation of the Crudo Ligero Marino project as a stand-alone project, thereby separating it from the Strategic Gas Program of which it formed part from 2001 through 2012. In 2013, the Och-Uech-Kax project was integrated into this project. The main objectives for the Crudo Ligero Marino project during the years 2018 to 2035 are to continue constructing one marine structure, in addition to the marine structure completed during 2014, drill additional wells, implement secondary recovery, as well as intervention, optimization and maintenance techniques to its

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facilities, particularly in the Sinan, Kab and Kax fields. As of December 31, 2017, a total of 99 wells had been completed at this project, of which 38 were producing. During 2017, average daily production totaled 80.9 thousand barrels of crude oil and 252.2 million cubic feet of natural gas. As of December 31, 2017, cumulative production was 874.2 million barrels of crude oil and 2,477.8 billion cubic feet of natural gas. Proved oil and gas reserves totaled 98.5 million barrels of crude oil and 278.7 billion cubic feet of natural gas. Total proved reserves were 156.5 million barrels of oil equivalent, of which 122.4 million barrels were proved developed reserves.

In nominal peso terms, our exploration and production segment’s capital expenditures for the Crudo Ligero Marino project totaled Ps. 1,026 million in 2017. For 2018, we anticipate our capital expenditures to total Ps. 3,722 million and that total accumulated capital expenditures for this project will reach approximately U.S. $207.4 million.

Ogarrio-Sánchez Magallanes Project. The Ogarrio-Sánchez Magallanes project is composed of 21 crude oil and natural gas producing fields and forms part of the Cinco Presidentes business unit. This project is located between the state borders of Veracruz and Tabasco and covers an area of 10,820 square kilometers. From a geological standpoint, this project pertains to the Isthmus Saline basin, specifically the southeastern basins at the Tertiary level. The Ogarrio-Sánchez Magallanes project is geographically bounded by the Gulf of Mexico to the north, the geological folds of the Sierra Madre of Chiapas to the south, the Tertiary basin of Veracruz to the west and the Comalcalco Tertiary basin to the east. The primary objective of this project is to increase production levels through the drilling of development wells and infill wells, which are drilled between producing wells to more efficiently recover oil and gas reserves, the execution of workovers of wells and the implementation of secondary and enhanced oil recovery processes. In addition, we aim to optimize the infrastructure of this project in order to counteract the decreases in production levels that result from the natural depletion of its reservoirs.

As of December 31, 2017, the Ogarrio-Sánchez Magallanes project had 524 producing wells. No new wells were completed during 2017. Average daily production totaled 63.1 thousand barrels of crude oil and 109.1 million cubic feet of natural gas during 2017. As of December 31, 2017, cumulative production was 1.3 billion barrels of crude oil and 1.9 trillion cubic feet of natural gas. Proved hydrocarbon reserves totaled 115.6 million barrels of crude oil and 212.7 billion cubic feet of natural gas. Total proved reserves were 154.8 million barrels of oil equivalent, of which 137.1 million barrels were proved developed reserves.

In nominal peso terms, our capital expenditures for the Ogarrio-Sánchez Magallanes project were Ps. 1,063 million in 2017. For 2018, we anticipate that our capital expenditures will total Ps. 1,375 million and that by the end of 2018 total accumulated capital expenditures for this project will reach approximately U.S. $82.0 million.

Delta del Grijalva Project. The Delta del Grijalva project is the most important project in the Southern region in terms of both oil and gas production. The project covers an area of 1,343 square kilometers and has been exploited by our exploration and production segment since 1982. As of December 31, 2017, there was a total of 199 wells drilled, of which 46 were producing. During 2017, the project produced an average of 63.0 thousand barrels per day of crude oil and 266.0 million cubic feet per day of natural gas. The most important fields are Terra, Tizón, Sen and Caparroso-Pijije-Escuintle.

• Terra. This field covers an area of 13.7 square kilometers. As of December 31, 2017, a total of 16 wells had been completed, 11 of which were producing. During 2017, the field produced an average of 15.9 thousand barrels per day of crude oil and 60.9 million cubic feet per day of natural gas. As of December 31, 2017, cumulative production was 49.4 million barrels of crude oil and 159.7 billion cubic feet of natural gas. As of December 31, 2017, total proved reserves were 22.1 million barrels of oil equivalent, 9.7 million of which were proved developed reserves.

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• Sen. This field covers an area of 45.1 square kilometers. As of December 31, 2017, a total of 49 wells had been completed, 11 of which were producing. During 2017, the field produced an average of 4.4 thousand barrels per day of crude oil and 13.1 million cubic feet per day of natural gas. As of December 31, 2017, cumulative production was 314.4 million barrels of crude oil and 862.8 billion cubic feet of natural gas. Proved hydrocarbon reserves totaled 11.6 million barrels of crude oil and 39.8 billion cubic feet of natural gas. As of December 31, 2017, total proved reserves were 21.1 million barrels of oil equivalent, 14.5 million of which were proved developed reserves.

• Caparroso-Pijije-Escuintle. This field covers an area of 28.2 square kilometers. As of December 31, 2017, a total of 53 wells had been completed, 16 of which were producing. During 2017, the field produced an average of 8.7 thousand barrels per day of crude oil and 27.9 million cubic feet per day of natural gas. As of December 31, 2017, cumulative production was 234.5 million barrels of crude oil and 659.0 billion cubic feet of natural gas. Proved hydrocarbon reserves totaled 8.8 million barrels of crude oil and 28.2 billion cubic feet of natural gas. As of December 31, 2017, total proved reserves were 15.5 million barrels of oil equivalent, 11.8 million of which were proved developed reserves.

• Tizón. This field covers an area of 17.8 square kilometers. As of December 31, 2017, a total of 17 wells had been completed, 11 of which were producing. During 2017, the field produced an average of 23.5 thousand barrels per day of crude oil and 130.1 million cubic feet per day of natural gas. As of December 31, 2017, cumulative production was 85.0 million barrels of crude oil and 485.2 billion cubic feet of natural gas. Proved hydrocarbon reserves totaled 18.4 million barrels of crude oil and 101.7 billion cubic feet of natural gas. As of December 31, 2017, total proved reserves were 42.6 million barrels of oil equivalent, 41.7 million of which were proved developed reserves.

As of December 31, 2017, cumulative production in the Delta del Grijalva project was 0.8 billion barrels of crude oil and 3.0 trillion cubic feet of natural gas. Proved oil and gas reserves as of December 31, 2017 totaled 66.0 million barrels of crude oil and 299.2 billion cubic feet of natural gas. As of December 31, 2017, total proved reserves were 137.0 million barrels of oil equivalent, 88.3 million of which were proved developed reserves.

In nominal peso terms, our exploration and production segment’s capital expenditures for the Delta del Grijalva project were Ps. 4,687 million in 2015, Ps. 2,859 million in 2016 and Ps. 1,705 million in 2017. In 2018, we expect our capital expenditures to be Ps. 675 million, bringing our total capital expenditures for the project to approximately U.S.$ 42,390 billion.

Antonio J. Bermúdez Project. In 2002, we began investing in the Antonio J. Bermúdez project, the main investment project in the Southern region and the fifth largest in Mexico. This project is designed to accelerate reserves recovery, as well as increase the recovery factor by drilling additional wells and implementing a system of pressure maintenance through nitrogen injection. It consists of the Samaria, Cunduacán, Oxiacaque, Iride and Platanal fields, and covers an area of 163 square kilometers. As of December 31, 2017, a total of 845 wells had been completed, of which 230 were producing. During 2017, the project produced an average of 36.9 thousand barrels per day of crude oil and 160.1 million cubic feet per day of natural gas. As of December 31, 2017, cumulative production was 3.0 billion barrels of crude oil and 4.7 trillion cubic feet of natural gas. As of December 31, 2017, proved hydrocarbon reserves in this field totaled 125.8 million barrels of crude oil and 238.8 billion cubic feet of natural gas. As of December 31, 2017, total proved reserves were 184.1 million barrels of oil equivalent, of which 118.5 million were proved developed reserves.

In nominal peso terms, our exploration and production segment’s capital expenditures for the Antonio J. Bermúdez project were Ps. 5,352 million in 2015, Ps. 2,562 million in 2016 and Ps. 1,306 million in 2017. For 2018, we anticipate that our capital expenditures for this project will be Ps. 1,522 million and that our total accumulated investments in the project will reach approximately U.S. $30,849 billion.

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In March 2005, we entered into a contract with Praxair México, S. de R.L. de C.V. to build, own and operate a nitrogen cryogenic plant, which was completed in June 2008. After completing testing in July 2008, we began injecting 190 million cubic feet per day of nitrogen into the project. In 2017, we paid approximately Ps. 491.5 million to acquire nitrogen from this plant, which we used to inject approximately 25,097 million cubic feet per day until July 9, 2017, when the injection of nitrogen was suspended.

Burgos Project. The Burgos project is the largest producer of non-associated gas in Mexico. In 1997, our exploration and production segment, through Pemex-Exploration and Production, initiated a development program for the Burgos natural gas fields. The purpose of the Burgos project is to enable us to meet increasing domestic demand for natural gas. The fields in Burgos accounted for 13.8% of our total natural gas production in 2017. The project is located in northeastern Mexico.

During 2017, the Burgos project produced an average of 699.2 billion cubic feet per day of natural gas. As of December 31, 2017, the drilling of 7,977 wells had been completed, 2,982 of which were producing. The most important fields are the Nejo, Arcabuz-Culebra, Cuitláhuac, Cuervito, Velero and Santa Anita fields, which together produced 50.5% of the total production of the Burgos project in 2017.

Main Fields of the Burgos Project

(as of December 31, 2017)

	Nejo		Arcabuz- Culebra		Cuitláhuac		Velero		Cuervito		Santa Anita
Wells completed		407		968		443		219		135		79
Producing wells		198		516		185		137		84		60
2017 production of natural gas (million cubic feet per day)		134		87		53		32		23		26
Cumulative production of natural gas (billion cubic feet)		538.3		2,074.7		807.4		349.1		206.7		263.9
Proved reserves of natural gas (billion cubic feet)		112.0		72.7		85.0		34.3		95.6		55.5
Proved developed reserves		100.2		69.0		63.1		30.5		36.7		36.7
Proved undeveloped reserves		11.7		3.7		21.9		3.9		58.9		18.9

Source: Pemex Exploration and Production.

During 2017, proved reserves increased by 3.8 million barrels of oil equivalent, from 178.8 million barrels of oil equivalent in 2016 to 182.6 million barrels of oil equivalent in 2017, primarily due to a deceleration in the decline of the gas production rate in 2017.

In nominal peso terms, our exploration and production segment’s capital expenditures (including capital expenditures made pursuant to FPWCs) for the Burgos project were Ps. 5,855 million in 2015, Ps. 2,032 million in 2016 and Ps. 606 million in 2017. For 2018, we anticipate that our capital expenditures for this project will amount to Ps. 175 million and that our total accumulated capital expenditures will reach approximately U.S. $19,243 billion.

Aceite Terciario del Golfo Project (formerly Paleocanal de Chicontepec). The ATG project is located in the Northern region and covers an area of 4,243 square kilometers. This project comprises 29 fields, which are divided among eight sectors. As of December 31, 2017, there was a total of 4,569 wells completed, of which 1,984 were producing. The project produced an average of 34.4 thousand barrels of crude oil per day in 2017 as compared to 39.8 thousand barrels of crude oil per day in 2016, which represents a 13.6% decrease, and

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118.5 million cubic feet of natural gas per day in 2017 as compared to 142.5 million cubic feet of natural gas per day in 2016, which represents a 16.8% decrease. The decrease in crude oil and natural gas production was primarily due to the decline in pressure in certain reservoirs. As of December 31, 2017, cumulative production was 314.4 million barrels of crude oil and 688.2 billion cubic feet of natural gas. As of December 31, 2017, proved reserves totaled 441.8 million barrels of crude oil and 893.1 billion cubic feet of natural gas. Total proved hydrocarbon reserves were 620.1 million barrels of oil equivalent, of which 125.1 million barrels of oil equivalent were proved developed reserves.

During 2017, field development activities at the project included the drilling of 32 wells and the completion of 24 wells, all of which were classified as producing, reflecting a 100% success rate. As of December 31, 2017, 80% of the total producing wells were operating with artificial systems such as mechanical, pneumatic, hydraulic and electric pumping, while the remaining 20.0% were “flowing wells” that are classified accordingly because they did not require any means of artificial lift.

In nominal peso terms, our exploration and production segment’s capital expenditures for the ATG project were Ps. 2,817 million in 2015, Ps. 1,487 million in 2016 and Ps. 604 million in 2017. For 2018, we anticipate that our capital expenditures for this project will be Ps. 478 million and that total accumulated investments in this project will be approximately U.S. $51.9 billion.

Crude Oil Sales

During 2017, domestic consumption of crude oil amounted to approximately 769.0 thousand barrels per day, which represented 39.7% of our total crude oil production. Through PMI’s activities, we sold the remainder of our crude oil production abroad. Maya crude oil accounted for 89.7% of exported crude oil volume sold by PMI in 2017. See “—Business Overview—International Trading” in this Item 4.

The following table sets forth crude oil distribution for the past five years.

Crude Oil Distribution

	At December 31,										2017 vs. 2016
	2013		2014		2015		2016		2017
	(in thousands of barrels per day)										(%)
Production		2,522.1		2,428.8		2,266.8		2,153.5		1,948.3		(9.5	)
Distribution
Refineries		1,229.1		1,161.1		1,064.0		935.0		769.0		(17.8	)
Export terminals		1,190.4		1,148.6		1,177.7		1,198.7		1,167.8		(2.6	)
Total		2,419.5		2,309.7		2,241.7		2,133.7		1,936.7		(9.2	)
Statistical differences in stock measurements(1)		102.6		119.1		25.2		19.8		7.8		46.6

Note: Numbers may not total due to rounding.

(1) Includes measurement inconsistencies, shrinkage and leakage, naphthas and condensates added to crude oil.

Source: Pemex Exploration and Production.

Differences between the volume of crude oil measured at the wellhead and the volume distributed reflect customary adjustments due to, among other things, shifting inventories, evaporation, shrinkage and product segregation. In August 2014, we identified increases in the difference between the volumes of crude oil production and distribution. Based on an analysis conducted in coordination with the CNH, we implemented various corrective measures to improve our measurement methodology and management system, including continuously monitoring our wells, calibrating our measurement equipment and installing additional crude oil

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dehydration systems. To this end, sediment tanks have also been installed at marine terminals in order to accelerate water evaporation and crude oil stabilization in accordance with industry standards. In addition, crude oil barrels undergo a stabilization process in preparation for export, which involves certification by us, the buyer and a third party to verify that the contents meet international standards and contain no more than 0.5% water.

Gas Flaring

The flaring of produced gas, which consists of the burning off of surplus combustible vapors from a well, usually occurs as a result of operational adjustments to carry out maintenance at production facilities, and in some cases is due to limitations in the ability to handle, process or transport natural gas. In addition, the flaring of produced gas is also used as a safety measure to relieve well pressure. Gas flaring is considered to be one of the most significant sources of air emissions from offshore oil and gas installations. In 2017, gas flaring represented 4.3% of total natural gas production, as compared to 8.8% of total natural gas production in 2016. The increased gas flaring in 2016 was primarily due to an explosion that occurred at the Abkatún-A platform in February 2016, management of oils with high gas-oil ratio and failures in gas compression equipment on offshore platforms. For more information on the explosion at the Abkatún-A platform, see “—Health, Safety and Environmental Performance” in this Item 4. We continue to implement programs to reduce gas flaring and improve gas extraction efficiency, including strategies to optimize the exploitation of wells with high associated gas content at the Cantarell project. In addition, in March 2017, we agreed to certain programs with the CNH, including five projects for U.S. $3.0 billion, which may allow us to improve our gas utilization rate to up to 98.0% at our Ku-Maloob-Zaap business unit by 2020. We began to take action steps under this program in 2017 and are continuing to work towards increasing our gas utilization rate.

Pipelines

The crude oil and natural gas pipeline network owned by our exploration and production segment connects crude oil and natural gas producing centers with refineries and petrochemical plants. At the end of 2017, this pipeline network consisted of approximately 38,754 kilometers of pipelines, of which 2,058 kilometers were located in the Northeast Marine region, 1,173 kilometers were located in the Southeast Marine region, 9,331 kilometers were located in the Southern region, 25,076 kilometers were located in the Northern region and 1,116 kilometers are distribution and commercial pipelines. For a description of products transported by the pipeline network, see “—Business Overview—Logistics” in this Item 4.

Integrated Exploration and Production Contracts and Financed Public Works Contracts

Our FPWC program, previously known as the Multiple Services Contracts program, was first announced in December 2001. The objective of the program was to provide a contractual framework that promotes efficient execution of public works in order to increase Mexico’s oil and gas production. The FPWC were public works contracts based on unit prices that aggregate a number of different services into a single contract. Under the FPWC framework, Pemex-Exploration and Production retained the rights and title to all oil and gas produced and works performed under each FPWC.

Our Integrated E&P Contracts program was established as part of reforms to the Mexican energy sector enacted in 2008. The objective of these Integrated E&P Contracts was to increase our execution and production capabilities. The oil and gas reserves located in and extracted from the areas to which we have a legal right, continue to be owned exclusively by the Mexican Government. Under this program, payments to the contractors were made on a per-barrel basis, plus recovery costs, provided that the payments did not exceed our cash flow from the particular block.

We may amend our Integrated E&P Contracts and FPWCs in order to align these contracts with the new contractual framework established under the Hydrocarbons Law. According to the Energy Reform Decree and the new contractual framework established under the Hydrocarbons Law, an existing Integrated E&P Contract or FPWC may be migrated into a contract for exploration and production upon agreement by the contract parties to

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the technical guidelines established by the Ministry of Energy (after seeking our favorable opinion) and the financial terms determined by the Ministry of Finance and Public Credit. Upon approval by the contract parties, the existing Integrated E&P Contract or FPWC will be replaced by the new contract for exploration and production without the need for a bidding process. If the contract parties do not agree to the proposed technical guidelines and contractual and financial terms, the original Integrated E&P Contract or FPWC will remain in effect.

On December 19, 2014, we and the relevant counterparties requested that the Ministry of Energy migrate the Integrated E&P Contracts governing the Santuario, Magallanes, Altamira, Arenque, Ébano, Miquetla and Pánuco blocks, and the FPWC governing the Misión and Olmos blocks, into new contracts for exploration and production. Parties to the FPWC governing the Nejo block and parties to the Integrated E&P Contract governing the San Andrés block made similar requests on November 24, 2015 and December 1, 2015. As part of the migration process, the Ministry of Energy, Ministry of Finance and Public Credit and the CNH requested further information on the proposed fiscal and technical terms of the new contracts, which Pemex Exploration and Production provided. On December 7, 2015, January 29, 2016 and May 11, 2016, the parties to the Altamira, San Andrés and Nejo blocks, respectively, withdrew their request for migration. We continue to evaluate the business case for the Altamira and San Andrés blocks and in the future may re-submit our request for migration of the Integrated E&P Contracts for those blocks.

The migration of Integrated E&P Contracts and FPWCs into contracts for exploration and production has taken longer than expected. As of the date of this annual report, the Integrated E&P contract for the Santuario block in the Southern region of Mexico was migrated on December 18, 2017 and we expect the FPWC for the Misión block in the Burgos basin will be migrated into contracts for exploration and production in the first six months of 2018.

Among the FPWC works during 2017, maintenance activities were carried out in the Burgos project under the FPWC program. The work carried out in 2017 represented an investment of approximately U.S. $99.0 million. In 2017, natural gas production in the existing FPWC blocks reached 238.0 million cubic feet per day.

During 2017, contractors expended approximately U.S $251.4 million in connection with Integrated E&P Contracts. In 2017, production in the existing Integrated E&P blocks reached 34.1 thousand barrels per day of crude oil and 58.1 million cubic feet per day of natural gas, for a total of 45.7 thousand barrels of oil equivalent per day.

New Exploration and Production Contracts and Farm-Outs

As a result of the opportunities made available to us by the energy reform, we have pursued farm-outs and other partnerships in order to diversify and strengthen our exploration and production portfolio and to focus on the most profitable projects. Through farm-outs, we sell a partial interest in fields that have been granted to us and enter into agreements for the joint operation of such fields. This requires third parties to make financial contributions to the partnership and to provide field services, allowing us to recoup some of our previous investments in the fields and to share some of the risk associated with the further development of the fields, while maintaining an interest in the future profits.

Trión Farm-Out

On July 28, 2016, the CNH published the tender offer and bidding package to select a partner for Pemex Exploration and Production to carry out exploration and production activities in the Trión block field

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assignments located in the Perdido Fold Belt in the Gulf of Mexico. Since the Trión block has a depth greater than 2,500 meters, it requires a high level of technical expertise and financial investment to develop.

On December 5, 2016, the CNH announced that BHP Billiton Petróleo Operaciones de México, S. de R.L. de C.V., or BHP Billiton Mexico, an affiliate of BHP Billiton Limited and BHP Billiton Plc, had been selected as the partner for Pemex Exploration and Production in the Trión block farm-out. Pursuant to the terms of its bid, BHP Billiton Mexico will make a U.S. $789.6 million contribution to the partnership in exchange for a 60% participating interest in the Trión Block. BHP Billiton Mexico will be the operator of the Trión block, and must invest U.S. $1.9 billion in the Trión farm-out before we are required to invest in the project, which, depending on the timeline set by the consortium, will likely be in four to five years. The corresponding exploration and production contract, joint operating agreement and other relevant agreements were executed on March 3, 2017 and we are currently working on the development stages of this project.

Nobilis-Maximino Farm-Out

On April 27, 2017, our Board of Directors authorized the farm-out of the Nobilis-Maximino Block, which is located in ultra-deep waters in the area of the Perdido Fold Belt in the Gulf of Mexico and, on September 18, 2017, the CNH published the announcement for the international public bidding process corresponding to that block. On December 8, 2017, however, we announced that, due to the high geological complexity of this ultra-deep-water field, as well as prevailing market conditions affecting the oil industry, we are delaying the farm-out of the Nobilis-Maximino block. We continue to seek partners and evaluate opportunities for the Nobilis-Maximino farm-out, including through potential future bidding rounds.

Ogarrio, Cárdenas-Mora and Ayin-Batsil Farm-Outs

In addition to the Trión and Nobilis-Maximino farm-outs, on October 4, 2017, the CNH held a bidding round for farm-outs of the Ogarrio, Cárdenas-Mora and Ayin-Batsil blocks. No bids were received for the Ayin-Batsil block, which is located in the shallow waters of the Gulf of Mexico. However, multiple bids were received for the Ogarrio block, which currently produces approximately 6,000 barrels of crude oil per day and 21 million cubic feet of natural gas per day, and the Cárdenas-Mora block, which currently produces approximately 5,000 barrels of crude oil per day and 18 million cubic feet of natural gas per day. The Ogarrio and Cárdenas-Mora blocks, both onshore fields located in the state of Tabasco, were ultimately awarded to the German company Deutsche Erdoel AG (DEA) and the Egyptian company Cheiron Holdings Limited (Cheiron), respectively. DEA’s bid consisted of an initial cash payment of U.S. $190.0 million, a royalty rate of 13% and an additional cash payment of U.S. $213.9 million, which is the highest sign-up bonus submitted in a CNH bidding round as of the date of this annual report. Cheiron’s bid consisted of an initial cash payment of U.S. $ 125.0 million, a royalty rate of 13% and an additional cash payment of U.S. $41.5 million. The corresponding contracts were signed on March 6, 2018 and have a term of 25 years. We retain a 50% interest in both blocks.

Other Exploration and Production Contracts

In addition to the farm-outs described above, we have also pursued other types of partnerships for the exploration and production of fields that were not already granted to us.

On December 5, 2016, we participated in the bidding process referred to as Round 1.4, through which we, as part of a consortium consisting of Pemex Exploration and Production, Chevron Energía de Mexico, S. de R.L. de C.V., or Chevron Energía, a subsidiary of Chevron Corporation, and INPEX Corporation, were awarded an exploration contract for a field located in the Perdido Fold Belt in the Gulf of Mexico. The field covers an area of approximately 1,686.9 square kilometers and is located approximately 117 kilometers off the coast of Mexico in water depths ranging between 500 meters and 1,700 meters. Chevron Energía will be the operator and holds a 33.3334% interest in the consortium, while Pemex Exploration and Production and INPEX Corporation each hold a 33.3333% interest. The corresponding exploration and production contract, joint operating agreement and other relevant agreements were executed on February 28, 2017.

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On May 2, 2017, Pemex Exploration and Production entered into a contract for crude oil extraction with the CNH to upgrade the assignments under the shared shallow water production scheme for the Ek and Balam project area located in Campeche Sound. This project is in line with our stragegy as contemplated by the 2017-2021 Business Plan to accelerate the development of fields, making it possible to reach the maximum recovery factor and significantly increase production. Under the contract, which has a term of twenty-two years with two possible five-year extensions, Pemex Exploration and Producion will pay the Mexican Government 70.5% of the operating profits and has provided a guarantee of U.S. $5.0 billion.

On May 30, 2017, we obtained approval from the CNH for the assignment of a new area that includes Chachiquin, located in the Cinturón Plegado Perdido region in the deep waters of the Gulf of Mexico south of the maritime border with the U.S., and an area southwest of the Nobilis field.

On June 19, 2017, we participated in another bidding round conducted by the CNH, referred to as Round 2.1. As a result of this bidding process, we won two blocks. We were awarded Block 2, which covers an area of 549 square kilometers and is located on the continental shelf of the Tampico-Misantla basin, to the west of the Gulf of Mexico, in partnership with DEA. We are the operating partner in this block and own a 70% interest. Additionally, we were awarded Block 8, which is located in the Southeastern Basins and covers an area of 586 square kilometers, in partnership with Colombia’s Ecopetrol. In Block 8, we are also the operating partner and own a 50% interest. The corresponding contracts for the exploration and extraction of hydrocarbons with DEA and Ecopetrol were signed on September 25, 2017.

On December 18, 2017, we executed contracts for an association with Petrofac México, S.A. de C.V., or Petrofac, under which we assigned to Petrofac the rights to certain fields that were part of the El Golpe-Puerto Ceiba project, including the onshore fields of Santuario, El Golpe and Caracolillo, located in the state of Tabasco. As of December 31, 2017, we still own 64% of the proved reserves in this project.

On January 31, 2018, we successfully participated in bidding Round 2.4, and were awarded the assignment of four blocks, all of which are located in deep waters in the Gulf of Mexico. Pemex Exploration and Production and Royal Dutch Shell PLC were awarded Block 2 of the Perdido area. The consortium formed by Pemex Exploration and Production, Chevron and INPEX was awarded area 22 of the Cuenca Salina province. Finally, we were assigned Block 5 in the Perdido area and area 18 of the Mexican Range province.

On March 27, 2018, we successfully participated in the first call of bidding Round 3 of the NCH, and were awarded seven contractual areas in shallow waters, six of them as part of a consortium and one on an individual basis. Pemex Exploration and Production won four blocks in the Southeast Basins: two in consortium with Total S.A., one with Shell Oil Company and one individually, as well as three blocks corresponding to the province of Tampico-Misantla-Veracruz: two in partnership with Compañía Española de Petróleos and one in partnership with DEA.

Collaboration and Other Agreements

Pemex Exploration and Production, or its predecessor Pemex-Exploration and Production, have entered into non-commercial scientific and technology agreements with the following parties, which remain in effect as of the date of this annual report:

• BP Exploration Operating Co. Ltd. during 2012;

• Statoil Mexico A.S., ExxonMobil Ventures Mexico Ltd., Japan Oil, Gas and Metals National Corporation, Chevron Deepwater Mexico Inc., BG North America LLC during 2013; and

• Itera Group LLC, during 2013.

Pemex Exploration and Production did not enter into any collaboration agreements in 2017.

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Through these agreements, we seek to increase our technical and scientific knowledge in areas including deepwater subsalt exploration and drilling; enhanced oil recovery processes, such as air injection; and reservoir characterization of complex structures. These broad agreements of technological and scientific collaboration are strictly non-commercial, i.e., there is no transfer of resources and they do not establish a binding relationship among the parties.

Industrial Transformation

Our industrial transformation segment is comprised of two principal activities: (i) refining and (ii) gas and aromatics.

Refining

Refining Processes and Capacity

Our refining production processes include the following:

• Atmospheric distillation. This process heats crude oil in a tube furnace at atmospheric pressure to distill refined products. The primary products produced are gasoline, jet fuel, diesel, atmospheric gas oil and atmospheric residual crude oil.

• Vacuum distillation. This process heats crude oil or other feedstock in a vacuum distillation column, which is operated at low pressures. The objective of this process is to maximize production of heavy vacuum gas oil, which is produced by boiling crude oil.

• Cracking. This process uses either heat and pressure or a catalytic agent to increase gasoline yields from crude oil.

• Visbreaking. This is a thermal cracking process, which uses a horizontal-tube heater fired to a high temperature. Visbreaking reduces flasher bottom viscosity and produces some heavy gas oil.

• Reforming processes. These processes use heat and catalysts to transform smaller or unstable hydrocarbon molecules into larger, more useful refining or blending products. For example, we use reforming processes to convert low octane gasoline into higher octane stocks that are suitable for blending into finished gasoline and to convert naphthas into more volatile, higher octane products.

• Hydrotreatment or residual hydrocracking. This process uses a catalyst and hydrogen at high temperature and pressure to remove sulfur, nitrogen and some aromatic compounds. Hydrotreatment also processes some lighter liquid product off-take.

• Alkylation and isomerization. This polymerization process unites olefins and isoparaffins. Butylenes and isobutanes are combined with sulfuric acid or hydrofluoric acid to rearrange straight-chain hydrocarbon molecules into branched-chain products. Pentanes and hexanes, which are difficult to reform, are isomerized through the use of aluminum chloride and other precious-metal catalysts. Normal butane may be isomerized to provide a portion of the isobutane feed needed for the alkylation process. The process produces a high octane, low sensitivity blending agent for gasoline.

• Coking. This process is a severe method of thermal cracking used to upgrade heavy residuals into lighter products or distillates. Coking produces straight-run gasoline (coker naphtha) and various middle-distillate fractions used as catalytic feedstock, thus generating a concentrated solid material.

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These production processes together constitute our production capacity as set forth in the table below.

Refining Capacity by Production Process

	At December 31,
	2013		2014		2015		2016		2017
	(in thousands of barrels per day)
Production Process
Atmospheric distillation		1,690.0		1,602.0		1,640.0		1,602.0		1,627.0
Vacuum distillation		832.0		767.5		772.4		767.5		772.2
Cracking		422.5		422.5		422.5		422.5		422.5
Visbreaking		91.0		91.0		91.0		91.0		91.0
Reforming		279.3		279.3		279.3		279.3		279.3
Hydrotreatment		1,067.5		1,067.5		1,099.9		1,230.0		1,230.0
Alkylation and isomerization		155.3		154.3		154.8		154.3		154.3
Coking		155.8		155.8		155.8		155.8		155.8

Source: Base de Datos Institucional (Pemex Institutional Database, or Pemex BDI).

As of December 31, 2017, we owned and operated six refineries: Cadereyta, Madero, Minatitlán, Salamanca, Salina Cruz and Tula. Our refineries consist of atmospheric and vacuum distillation units, where the bulk of crude oil input is processed. Secondary processing facilities include desulfurization units and facilities for catalytic cracking, reforming and hydrotreating. During 2017, our refineries processed 767.0 thousand barrels per day of crude oil (127.2 thousand barrels per day at Cadereyta, 44.6 thousand barrels per day at Madero, 86.4 thousand barrels per day at Minatitlán, 156.8 thousand barrels per day at Salamanca, 137.0 thousand barrels per day at Salina Cruz and 215.1 thousand barrels per day at Tula), which in total consisted of 456.4 thousand barrels per day of Olmeca and Isthmus crude oil and 310.4 thousand barrels per day of Maya crude oil. In recent years, we have been affected by operational difficulties at our auxiliary services facilities. In order to increase the processing of crude oil at our refineries and the production of petroleum products, we are implementing maintenance programs for critical equipment to improve the safety and reliability of our operating processes and to improve the performance levels of our refineries.

Since 1993, through our subsidiary company, P.M.I. Norteamérica, S.A. de C.V. (PMI-NASA), we have participated in a limited partnership with Shell Oil Company in a refinery located in Deer Park, Texas, which has the capacity to process 340 thousand barrels per day of crude oil. Under the Deer Park Limited Partnership agreement, PMI-NASA and Shell Oil Company each provide 50% of the refinery’s crude oil input and own 50% of the refinery’s output. This agreement is limited to the specific purpose of operating the Deer Park refinery.

Production

We produce a wide range of products derived from crude oil and natural gas, including LPG, gasoline, jet fuel, diesel, fuel oil, asphalts, lubricants and other refined products. In 2017, we produced 786.2 thousand barrels per day of refined products (including dry gas by-products of the refining process), as compared to 977.2 thousand barrels per day in 2016, representing a decrease of 19.5%. This decrease in refined products production was mainly due to a decrease in crude oil production as a result of the implementation of major maintenance programs at the Madero and Minatitlán refineries in the second half of the year. In addition, our Salina Cruz refinery was affected by natural disasters: In June of 2017, the refinery was forced into an emergency shutdown as a result of flooding caused by tropical storm “Calvin”, and on September 7, 2017, an earthquake caused the refinery to go into an automatic safety shutdown. These natural disasters did not result in structural damage to our Salina Cruz refinery, although our electrical power generators were affected, and operations resumed during November of 2017.

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The following table sets forth, by category, our production of petroleum products from 2013 through 2017.

Refining Production

	Year ended December 31,										2017 vs. 2016
	2013		2014		2015		2016		2017
	(in thousands of barrels per day)										(%)
Refinery Crude Oil Runs		1,224.1		1,155.1		1,064.5		933.1		767.0		(17.8	)
Refined Products
Liquefied petroleum gas		25.2		26.4		21.4		17.2		15.8		(8.1	)
Gasoline
Pemex Magna		360.5		290.9		272.5		150.6		11.0		(92.7	)
Ultra-Low Sulfur Magna		56.7		99.1		88.4		165.5		238.7		44.2
Pemex Premium(1)		19.8		30.8		16.8		7.7		5.6		(27.3	)
Base		0.2		0.8		3.6		1.6		1.8		12.5
Total		437.3		421.6		381.4		325.3		257.0		(21.0	)
Kerosene (Jet fuel)		60.8		53.4		47.8		42.8		40.5		(5.4	)
Diesel
Pemex Diesel(2)		217.7		186.9		191.5		130.1		87.4		(32.8	)
Ultra-Low Sulfur Diesel		92.1		97.8		83.0		85.1		63.8		(25.0	)
Others		3.7		1.9		0.2		1.0		2.4		140.0
Total		313.4		286.6		274.7		216.2		153.6		(29.0	)
Fuel oil(3)		268.8		259.2		237.4		228.1		217.3		(4.7	)
Other refined products
Asphalts		18.7		23.9		17.7		16.9		16.5		(2.4	)
Lubricants		4.4		3.7		2.3		3.0		1.9		(36.7	)
Paraffins		0.7		0.6		0.5		0.6		0.4		(33.3	)
Still gas		70.7		63.9		62.2		61.9		47.9		(22.6	)
Other refined products(4)		75.7		66.7		68.9		65.3		35.5		(45.6	)
Total		170.2		158.8		151.6		147.6		102.1		(30.8	)
Total refined products		1,275.8		1,206.1		1,114.3		977.2		786.2		(19.5	)

Note: Numbers may not total due to rounding.

(1) Pemex Premium is an ultra-low sulfur gasoline with 0.003% sulfur content.

(2) Pemex Diesel is sold in the northern border market with 0.003% sulfur content.

(3) Includes heavy fuel oil and intermediate 15.

(4) Includes mainly coke, along with other products such as aeroflex, furfural extract, and light cyclic oil.

Source: Pemex BDI.

Fuel oil, automotive gasoline and diesels represent the bulk of our production. In 2017, gasoline represented 32.7%, fuel oil represented 27.6% and diesel fuel represented 19.5% of total petroleum products production. Jet fuel represented 5.2% and LPG represented 2.0% of total production of petroleum products in 2017. The remainder, 13.0%, of our production consisted of a variety of other refined products.

As a result of our strategy of investing in technology to improve the quality of our fuels, we have introduced new environmentally sound products such as ultra-low sulfur gasoline (or ULSG) and ultra-low sulfur diesel (or ULSD).

In recent years, our production has been affected by operational problems in our auxiliary services facilities. In order to improve production, our 2017-2021 Business Plan includes measures to ensure the supply of auxiliary services through partnerships with third parties. On September 1, 2017, we entered into long-term agreements

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with Air Liquide for the supply of hydrogen to our Tula refinery. Air Liquide will operate the existing hydrogen plant and will invest in the construction of a second plant at our Tula refinery. Air Liquide intends to provide the total supply of hydrogen required for both the existing and new plant.

Additionally, in October 2017, we began the process of selecting partners that will supply the hydrogen for our Madero and Cadereyta refineries, and in April of 2018, we entered into a long-term agreement with the German company Linde AG for the supply of hydrogen to our Madero refinery. We expect that by carefully selecting partners we will be able to reduce the cost and improve the reliability of the supply of hydrogen, which, in turn, we believe will improve the reliability of our crude oil refining and decrease unscheduled stoppages. We also expect that these projects will strengthen the operational performance of our Tula, Madero and Cadereyta refineries and increase the production of gasoline and diesel.

Variable Refining Margin

During 2017, the National Refining System recorded a variable refining margin of U.S. $5.43 per barrel, an increase of U.S. $0.95 per barrel as compared to U.S. $4.48 in 2016. This is broadly the result of the recovery in international prices for refined products in 2017.

The following table sets forth the variable refining margin for the five years ended December 31, 2017.

Variable Refining Margin

	Year ended December 31,											2017 vs. 2016
	2013			2014		2015		2016		2017
	(U.S dollars per barrel)											(%)
Variable margin		(1.84	)		1.76		3.35		4.48		5.43		21.2

Domestic Sales

We market a full range of refined products, including gasoline, jet fuel, diesel, fuel oil and petrochemicals. We are one of a few major producers of crude oil worldwide that experiences significant domestic demand for our refined products.

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For the five years ended December 31, 2017, the value of our domestic sales of refined products and petrochemicals was as follows:

Value of Refining’s Domestic Sales⁽¹⁾

	Year ended December 31,										2017 vs. 2016
	2013		2014		2015		2016		2017
	(in millions of pesos)(2)										(%)
Refined Products
Gasoline
Pemex Magna	Ps.	340,750.7	Ps.	347,952.4	Ps.	274,006.9	Ps.	248,595.2	Ps.	361,021.7		45.2
Pemex Premium		63,723.1		80,058.9		81,813.5		87,422.8		82,028.7		(6.2	)
Aviation fuels (Others)		414.1		387.5		339.8		342.4		371.1		8.4
Total		404,887.9		428,398.8		356,160.2		336,360.4		443,421.5		31.8
Kerosene (Jet fuel)		35,417.9		36,449.3		27,077.2		28,945.2		39,024.5		34.8
Diesel
Pemex Diesel		178,929.4		194,545.6		139,796.2		117,556.3		181,854.4		54.7
Others		32,542.0		31,156.7		22,930.4		19,236.4		28,195.1		46.6
Total		211,471.4		225,702.4		162,726.7		136,792.7		210,049.5		53.6
Fuel oil
Total		78,001.8		46,838.3		25,906.0		16,436.3		35,622.9		116.7
Other refined products
Asphalts		7,865.4		10,788.0		7,575.5		5,468.7	$	5,895.8		7.8
Lubricants		2,991.2		2,618.9		1,297.5		1,473.0		1,061.4		(27.9	)
Paraffins		339.4		319.2		257.9		267.0		230.9		(13.5	)
Coke		473.4		763.3		669.5		501.9		421.1		(16.1	)
Citroline		2.3		0.4		0.9		4.6		3.6		(21.7	)
Gas oil for domestic use		273.1		432.2		587.4		424.2		0.0		(100.0	)
Total	Ps.	11,944.8	Ps.	14,921.9	Ps.	10,388.8	Ps.	8,139.4	Ps.	7,612.8		(6.5	)
Total Refined Products	Ps.	741,723.8	Ps.	752,310.8	Ps.	582,258.9	Ps.	526,673.9	Ps.	735,731.2		39.7
Petrochemicals(3)	Ps.	6,882.8	Ps.	7,582.2	Ps.	3,930.9	Ps.	3,118.0	Ps.	3,905.6		25.3

Note: Numbers may not total due to rounding.

(1) Excludes IEPS tax and value added tax. See “—Taxes, Duties and Other Payments to the Mexican Government” in this Item 4.

(2) Figures are stated in nominal pesos. See “Item 3—Key Information—Selected Financial Data.”

(3) Petrochemical products produced at refineries operated by our industrial transformation segment (carbon black feedstocks and propylene).

Source: Pemex BDI.

In 2017, our domestic sales of refined products increased by Ps. 209,057 million, or 39.7% in value, as compared to 2016 levels (excluding IEPS tax and value added tax). This was primarily due to a 31.8% increase in the value of our gasolines sales, an increase of 53.6% in the value of diesel sales and a 116.7% increase in the value of fuel oil, in each case primarily as a result of higher average prices.

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The volume of our domestic sales of refined products for the five-year period ended December 31, 2017 was distributed as follows:

Volume of Refining’s Domestic Sales

	Year ended December 31,										2017 vs. 2016
	2013		2014		2015		2016		2017
	(in thousands of barrels per day, except where otherwise indicated)										(%)
Refined Products
Gasoline
Pemex Magna		667.6		639.1		638.0		637.5		660.5		3.6
Pemex Premium		119.2		137.1		154.8		185.1		136.6		(26.2	)
Aviation fuels (Others)		0.5		0.5		0.5		0.5		0.5		—
Total		787.3		776.7		793.3		823.1		797.5		(3.1	)
Kerosenes (jet fuel)		62.2		66.5		70.8		76.2		81.7		7.2
Diesel
Pemex Diesel		333.2		336.4		330.6		335.5		317.6		(5.3	)
Others		58.5		53.0		54.2		51.8		47.9		(7.5	)
Total		391.7		389.4		384.7		387.2		365.5		(5.6	)
Fuel oil
Total		189.3		121.7		111.7		102.6		124.7		21.5
Other refined products
Asphalts		17.3		21.7		15.9		15.9		15.4		(3.1	)
Lubricants		4.7		4.0		2.6		3.1		2.0		(35.5	)
Paraffins		0.7		0.6		0.6		0.6		0.4		(33.3	)
Coke		47.8		46.0		45.9		36.3		21.3		(41.3	)
Citroline		—		—		—		0.01		0.01		—
Gas oil for domestic use		0.7		0.9		1.2		0.9		—		(100.0	)
Total		71.2		73.3		66.2		56.9		39.1		(31.3	)
Total refined products		1,501.8		1,427.6		1,426.7		1,446.0		1,408.4		(2.6	)
Petrochemicals(1)(2)		738.8		703.8		620.9		543.5		464.5		(14.5	)

Note: Numbers may not total due to rounding.

(1) In thousands of metric tons.

(2) Petrochemical products produced at refineries operated by our refining business (black feedstocks and propylene).

Source: Pemex BDI.

The volume of our domestic gasoline sales decreased by 3.1% in 2017, from 823.1 thousand barrels per day in 2016 to 797.5 thousand barrels per day in 2017. The volume of our diesel sales decreased by 5.6%, from 387.2 thousand barrels per day in 2016 to 365.5 thousand barrels per day in 2017. The decrease in the volume of our domestic gasoline and diesel sales is mainly due to lower demand in the first quarter of 2017, which in turn was primarily the result of an increase in average gasoline and diesel prices. The volume of our domestic sales of fuel oil increased by 21.5%, from 102.6 thousand barrels per day in 2016 to 124.7 thousand barrels per day in 2017, primarily due to an increase in CFE’s demand for fuel oil.

Sales of Pemex Premium gasoline decreased 26.2% in 2017, while those of Pemex Magna increased 3.6% from the previous year. This change in consumption patterns is the result of an increase in the price differential between the two kinds of gasolines.

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We have also made concerted efforts to build and enhance our brands. As a result of energy reform, beginning in April 2016, the Mexican government has allowed private companies, including third-party franchises, to participate as retailers in the Mexican gasoline market and purchase gasoline products from us or import these same products from abroad. Pursuant to this regulatory change, on June 5, 2016, we announced that a joint branding program had been established with various entities that own and operate retail service stations in Mexico. The joint branding program allowed our franchisees to rename their retail service stations while continuing to sell our products under our brand. In addition, we continued to provide technical and operational assistance to such franchisees. We believe that this program strengthened our relationship with entities that own and operate retail service stations in Mexico, as we continue to adapt to the new competitive pressures in the Mexican fuel market. The joint branding program ended on February 28, 2018, but a large number of franchisees opted to continue the commercial practices developed as part of the program.

On November 15, 2017, we relaunched the “Pemex Franchise” image program with a new business model that includes new products and a variety of new association schemes. The goal of this program is to provide better service to end users and to strengthen the PEMEX brand, particularly in response to the current competitive environment in the Mexican fuel market. We have improved the quality of our fuel types by blending our Pemex Magna and Pemex Premium gasoline with high-end additives. This formula was developed exclusively for us and is made with components that maximize the fuel’s performance, cleanliness and quality. As part of the program, we also introduced three association schemes: (i) PEMEX Franchise, (ii) sublicensing of branded products, and (iii) the sale of generic, unbranded products. We also have two options for wholesale distribution: (i) independent retailers of unbranded products, and (ii) associate distributors of PEMEX-branded gasoline and diesel. In order to strengthen and protect the PEMEX brand, we have established various controls to ensure that all service stations comply with our demand for high quality and honest service. Furthermore, we plan to launch a new generation of performance additive for our gasoline towards the end of 2018, which will be supported by significant promotional and advertising efforts.

At the end of 2017, there were 11,586 retail service stations in Mexico, of which 11,540 were privately owned and operated as franchises, while the remaining 46 were owned by Pemex Industrial Transformation. This total number of retail service stations represents a decrease of 2.4% from the 11,876 service stations as of December 31, 2016. Additionally, as of December 31, 2017, we served as the supplier for 454 retail service stations that operated under a brand other than the PEMEX brand.

Pricing Decrees

The energy reform provides for fuel price liberalization, which began in early 2017 and was completed by the end of that year. Even though prices have been fully liberalized, the CRE reserves the right to intervene. Therefore, our sales prices continue to be subject to potential future regulations by the CRE, until the Comisión Federal de Competencia Económica (Federal Economic Competition Commission) determines that there is effective competition in the wholesale market.

Gasoline and Diesel

Historically, the Mexican Government has established periodic increases on the price of gasoline and diesel.

On January 1, 2014, pursuant to the Impuesto a los Combustibles Fósiles (IEPS Tax on Fossil Fuels) approved under the Ley del Impuesto Especial sobre Producción y Servicios (Special Tax on Production and Services Law, or the IEPS Law), unleaded gasoline and diesel became subject to one-time price increases of ten and thirteen Mexican cents per liter, respectively. See “—Information on the Company—Taxes, Duties and Other Payments to the Mexican Government” in this Item 4.

During 2015, the Mexican Government imposed further one-time increases of approximately 26 Mexican cents per liter on Magna gasoline and diesel and 27 Mexican cents per liter on premium gasoline. As of

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January 1, 2016 the Mexican Government established a new mechanism to determine the prices of gasoline and diesel, which took into account international market prices. This mechanism allowed gasoline and diesel prices to float within a fixed range determined by the Mexican Government, adding a flat IEPS tax. At the end of 2016, prices of gasoline were approximately 43 Mexican cents per liter higher, as compared to 2015, and prices of diesel were approximately 43 Mexican cents per liter higher in 2016, as compared to 2015.

In January 2017, as part of the energy reform, the Mexican Government began to liberalize the price of gasoline and diesel. As a result, on January 1, 2017, magna gasoline prices increased sharply by between Ps. 1.35 and Ps. 2.61 per liter, as compared to December 31, 2016. Similarly, diesel prices increased by between Ps. 1.78 and Ps. 3.05 per liter on January 1, 2017, as compared to December 31, 2016.

The liberalization of prices continued in 2017 and, as of December 31, 2017, sale prices of gasoline and diesel have been fully liberalized and are determined by the free market. For more information, see “Item 5—Operating and Financial Review and Prospects—IEPS Tax, Hydrocarbon Duties and Other Taxes.”

Discount

Since the early 1980s, the Mexican Government has also established a discount of 30% on the price at which we sell gas oil intended for domestic use to the state of Chihuahua during the months of January, February and December of each year. On January 1, 2014, pursuant to the IEPS Tax on Fossil Fuels, such gas oil became subject to a one-time price increase of 10.857 Mexican cents per liter. Gas oil became subject to a one-time price increase of 11.307 Mexican cents per liter in 2015, 11.558 Mexican cents per liter as of January 1, 2016, 11.94 Mexican cents per liter as of January 1, 2017 and 12.73 Mexican cents per liter as of January 1, 2018. Notably, the discount on the price of gas oil in the state of Chihuahua was suspended in December 2016. As of the date of this annual report, this discount remains suspended.

Fuel Oil

Since December 2008, the price at which we sell fuel oil to CFE has been linked to international market prices in accordance with a pricing methodology established by the Mexican Government. This methodology is based on the price of fuel oil in the U.S. Gulf of Mexico coastal region, and is then adjusted for quality as well as expenses related to distribution.

On January 1, 2015, the IEPS Tax on Fossil Fuels of 14.00 Mexican cents per liter of fuel oil became effective through the fiscal year ended December 31, 2015. As of January 1, 2016, fuel oil became subject to a premium of 14.31 Mexican cents per liter and as of January 1, 2017, the IEPS Tax on Fossil Fuels is 14.78 Mexican cents per liter. As of January 1, 2018, the IEPS Tax on Fossil Fuels is 15.76 Mexican cents per liters.

As of November 3, 2017, the CRE authorized new formulas to determine the price for fuel oil. As of December 31, 2017, there are first-hand sale prices for sales at refineries and market prices for sales at storage and distribution terminals. These prices are calculated weekly and apply to all customers, including the CFE.

The Mexican Government could modify these price controls or impose additional price controls in the future. See “Item 3—Key Information—Risk Factors—Risk Factors Related to our Relationship with the Mexican Government—The Mexican Government has historically imposed price controls in the domestic market on our products.”

We withhold IEPS Tax. While it is included in the price to our customers, we pay this tax to the authorities upon collection of the sale of our products and it is not included in our revenues. For more information, see “Item 4—Taxes, Duties and Other Payments to the Mexican Government—Fiscal Regime for PEMEX.”

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Investments

Over the past several years, we have focused our investment program on enhancing the quality of the gasoline and diesel we produce to meet Mexico’s new environmental standards. Our aim is to improve our ability to process heavy crude oil in order to optimize the crude oil blend in our refineries and to increase production of unleaded gasoline and diesel to supply growing demand at a lower cost.

Our refining business invested Ps. 15,988 million in capital expenditures in 2017 and has budgeted Ps. 14,376 million in capital expenditures for 2018. We hope to complement our capital expenditures in 2018 through strategic alliances.

The following table sets forth our refining business’ capital expenditures, excluding non-capitalizable maintenance, for each of the three years ended December 31, 2017, and the budget for 2018. Capital expenditure amounts are derived from our budgetary records, which are prepared on a cash basis. Accordingly, these capital expenditure amounts do not correspond to capital expenditure amounts included in our consolidated financial statements prepared in accordance with IFRS.

Refining’s Capital Expenditures

	Year ended December 31,(1)						Budget 2018(2)
	2015		2016		2017
	(in millions of pesos)(3)
Refining
Fuel Quality Investments(4)	Ps.	9,045	Ps.	10,702	Ps.	5,196	Ps.	2,483
Reconfiguration of Miguel Hidalgo Refinery in Tula		4,674		8,610		1,912		303
New Refinery in Tula(5)		561		1,849		—		—
Minatitlán Refinery Energy Train		—		1,100		—		—
Cadereyta Refinery Energy Train		—		872		—		—
Residual Conversion from Salamanca Refinery		913		749		773		68
Tuxpan Pipeline and Storage and Distribution Terminals		100		15		67		71
Others		14,353		6,604		8,039		11,452
Total	Ps.	29,646	Ps.	30,501	Ps.	15,988	Ps.	14,376

Notes: Numbers may not total due to rounding.

(1) Amounts based on cash basis method of accounting.

(2) Budget presented to the Board of Directors of Petróleos Mexicanos on March 5, 2018.

(3) Figures are stated in nominal pesos.

(4) Includes clean fuels investments for gasoline and diesel in our six refineries.

(5) Includes pre-investments studies, on-site preparation and other expenses related to this project.

Source: Petróleos Mexicanos.

During 2017, we imported approximately 570.2 thousand barrels per day of gasoline, which represented approximately 71.5% of total domestic demand for gasoline in that year.

Our projects, which will involve some private sector investments, aim to reduce greenhouse gas emissions by promoting cleaner fuels. Certain of these projects, including the Fuels Quality Project (formerly known as the Clean Fuels Project), the reconfiguration of the Miguel Hidalgo Refinery in Tula and the residual conversion of the Salamanca Refinery, are already part of ongoing projects developed by our industrial transformation segment. Our projects are described in further detail below.

Fuel Quality Project

Our Fuel Quality Project is being developed in our six refineries, with a first phase involving the installation of eight ULSG post-treatment units, the capacities of which are set forth below by refinery. The first phase of this

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project was divided into thee groups of refineries: Group 1: Tula and Salamanca (which are both 100% completed, and which began operations in June 2016); Group 2, Cadereyta and Madero (which are both 100% completed and which began operations in February 2014 and July 2015, respectively); and Group 3, Minatitlán and Salina Cruz (which are both 100% completed and which began operations in December 2015 and August 2016, respectively). As a result of these projects, and as of the date of this annual report, all gasoline produced in Mexico meets international environmental standards. The consumption of cleaner fuels will allow us to reduce emissions of greenhouse compounds.

Plant Capacity

	Cadereyta			Madero			Minatitlán			Salamanca			Salina Cruz			Tula
ULSG units (tbpd)		1	(42)		2	(20)		1	(25)		1	(25)		2	(25)		1	(30)

Note: tbpd = thousand barrels per day.

ULSG: Ultra Low Sulfur Gasoline.

Source: Pemex Industrial Transformation.

In addition to the ULSG post-treatment units, we entered into 15 additional contracts during phase 1 of our Fuel Quality Project, of which two are in progress, eight have been completed, four have been temporarily suspended and one was terminated early. The status of these contracts is as follows, by refinery:

• Tula:

• tanks and laboratory: 100% completed;

• optimized automated integrated in-line mixing system (SIMLOA): 80% completed and temporarily suspended;

• parasitic gasolines: 83% completed and temporarily suspended;

• Salamanca:

• tanks and laboratory: 100% completed;

• parasitic gasolines: 100% completed;

• steam condensation station: 91% completed and temporarily suspended;

• Salina Cruz:

• Tanks and laboratory: 100% completed;

• Minatitlán:

• Laboratory: 100% completed;

• Cadereyta:

• SIMLOA: 61% completed and in progress;

• turbogenerator, 91% completed and temporarily suspended;

• Madero:

• laboratory: 55% completed and in progress; and

• turbogenerator: termination expected.

The second phase of the Fuel Quality Project involves the construction of five ULSD facilities, five hydrogen plants, four sulfur recovery units, five sour water treatment plants and the reconfiguration of 17 existing units to produce ULSD. The strategy for phase II consists of the following three stages: (i) early production, (ii) Cadareyta diesel and (iii) a diesel stage for the five remaining refineries, as described below.

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Early production. We executed projects to increase efficiency at certain of our existing processing plants and to produce ULSD through eight construction and services contracts totaling Ps. 130 billion. All of these projects have been completed and the respective plants are in operation.

Cadereyta diesel phase. Construction began in March 2013 and, as of the date of this annual report, is approximately 68% complete. Due to budgetary constraints, however, two of the four relevant contracts have been suspended since April 2016. We are currently evaluating funding alternatives through alliances and/or strategic partnerships in order to resume work under these two contracts and we anticipate that work may resume during the second quarter of 2018. The two other contracts have been completed.

Diesel phase for outstanding refineries. The Open Book Cost Estimation (OBCE) methodology is used in connection with the implementation of the diesel phase at the refineries other than Cadereyta and is divided into two stages:

Phase I: the development of detailed engineering plans and the placement of purchase orders for equipment requiring significant delivery time to determine a cost estimate for Phase II. Phase I was completed with the execution of the Final Works Agreement on December 17, 2015.

Phase II: the execution of detailed engineering, procurement and construction, which commenced in January 2016. Due to budgetary constraints, however, the project was suspended in October 2016 with only a small portion completed. We are currently evaluating funding alternatives through alliances and/or strategic partnerships in order to resume work under the contracts.

As of the date of this annual report, we also have 15 contracts for complementary facilities, which comprise the total scope of the Fuel Quality Project. Of those 15, five have been completed, eight are in development and two have been suspended as the result of budgetary constraints.

Reconfiguration of the Miguel Hidalgo Refinery in Tula

On August 12, 2009, we announced the construction of a new refinery in Tula on land that was donated by the state government of Hidalgo. Upon completion of our pre-investment studies relating to the new refinery in Tula, we determined that it would be more cost-effective to forgo construction of a new refinery and instead direct our investments to the reconfiguration of the existing Miguel Hidalgo refinery. Accordingly, on December 3, 2014, we announced the commencement of renovations to upgrade the refinery as part of the Aprovechamiento de Residuales en la Refinería de Tula Hidalgo (Residue Use at the Tula Hidalgo Refinery, which we refer to as the Tula refinery reconfiguration project). The reconfigured refinery is intended to (i) generally modernize crude oil processing; (ii) increase the efficiency with which vacuum residue is converted into high value fuels; (iii) produce higher value products; (iv) increase refining margins; and (v) reduce fuel oil handling problems.

Pemex Industrial Transformation plans to implement the reconfiguration project in two phases: (i) phase one for the development of engineering plans and (ii) phase two for detailed engineering, procurement and construction. In September 2013, ICA Fluor Daniel, S. de R.L. de C.V. (ICA Fluor) was awarded a U.S. $94.8 million contract to carry out studies and to provide engineering services for phase one. Site preparation work began in February 2014 and construction of the first processing unit began in October 2014.

By the end of 2016, the project was approximately 27% completed, but due to budgetary constraints certain tasks were delayed and rescheduled, including the construction of the coking plant. Construction of the new coking plant is part of the modernization of the refinery, which is intended to increase the production of various types of gasoline, diesel and jet fuel. We estimate that the modernization of the refinery will allow us to increase performance by over 40%, increasing production of refined oil products from 154 thousand barrels per day to 220 thousand barrels. The project is being carried out in two stages. The first stage, which is scheduled to be

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completed by 2020, includes the building and commissioning of the delayed coking plant and the facilities necessary for its operation. The second stage, which is scheduled to be completed in 2022, covers the remaining new facilities, the modernization of current facilities and their integration. As of March 31, 2018, construction of the coker plant was 60% completed and we are currently evaluating funding alternatives through alliances and/or strategic partnerships in order to complete construction.

Residual Conversion of the Salamanca Refinery

The reconfiguration of the “Ingeniero Antonio M. Amor” refinery in Salamanca, Guanajuato focuses on the conversion of residuals into high-value distillates (without a need for increased crude oil processing), as well as the modernization of the lubricants train to produce group II lubricants. As part of the reconfiguration, we will construct new plants and refurnish existing plants. This project also involves the construction of a perimeter wall surrounding the refinery with two security entrances, the relocation of CFE’s electric transmission lines and site improvements. Construction of the new plants includes a delayed coker unit, a catalytic cracking unit, a hydrogen plant, a coker naphthas hydro-desulfurization plant, a gasoil hydro-desulfurization plant, a new lubricants train, a naphtha reforming plant, a sulfur recovery unit, an amine regeneration unit and a sour water treatment facility. In addition, this project involves the construction of storage tanks, effluent treatment plants (at which industrial wastewater is treated for reuse) and infrastructure (including roads and street lights) in the areas surrounding the refinery, as well as services, electric power supply, high burner areas, buildings and other service and support facilities. Other units, including certain vacuum and atmospheric distillation units, will undergo renovations to enhance their ability to supply the coker plant and to increase the supply of gas oil to the new plants. Finally, the project includes the integration of pipelines, pumping equipment and electrical substations from existing facilities.

In accordance with the OBCE methodology, Pemex Industrial Transformation plans to implement the project in two phases as part of a strategy to increase efficiency, mitigate technical and economic risks, define the project’s scope and reduce uncertainty. Phase one includes the development of engineering plans, while phase two includes detailed engineering plans, together with procurement and construction. At the end of 2017, the project was approximately 12.8% complete and phase one was approximately 98% completed but has been suspended due to budgetary constraints. However, in light of the advanced engineering plans, site preparation and equipment design, this project is ready to commence procurement and construction and we are actively evaluating strategies and seeking partners to obtain funding to resume the project. See “—Investments” below for more information regarding capital expenditures by project.

Pemex Industrial Transformation, together with the Department of Corporate Alliances and New Business, is currently seeking partners to continue the project.

Tuxpan Maritime Terminal

The Tuxpan Maritime Terminal project is intended to help meet the increasing demand for refined products in the metropolitan area of the Mexico Valley. The total cost of the project is approximately Ps. 5,171.5 million, which includes the construction of a pipeline measuring 18 inches in diameter and 109 kilometers in length from Cima de Togo to Venta de Carpio, five storage tanks located at the Tuxpan Maritime Terminal with a capacity of 100,000 barrels each, a research study to determine the best option for the discharge of refined products from tankers and pipelines into these storage tanks and auxiliary and integration services.

As of April 2018, two of the three phases of this project, the pre-investment studies and the transportation of the Tuxpan-Mexico pipelines, have been completed, and the pipeline is in operation. The third phase, the storage system, is 98.4% complete, and we have requested an extension from the SHCP for additional time within which to complete this final phase. Four of the five storage tanks have been delivered to the Tuxpan Maritime Terminal and are operational. The remaining tank is 99.7% complete and the overall Tuxpan-Mexico pipelines project is expected to be completed in 2018.

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Maintenance at the Francisco I. Madero Refinery

On August 23, 2017, we commenced a scheduled gradual shutdown of our Francisco I. Madero refinery, located in Ciudad Madero, Tamaulipas in order to implement a comprehensive general maintenance program for the plants at this refinery. Operations at the plants were restarted in February 2018 and we are currently in the process of stabilizing operations. We expect that this program will lead to improved safety and reliability of our operating processes and, in turn, improved performance of this refinery.

Hydrogen Supply for Refineries

Pursuant to the energy reform and our 2017-2021 Business Plan, we aim to partner with third parties and to enter into strategic alliances and joint ventures for projects related to auxiliary services, such as the supply of hydrogen to refineries, which will permit us to specialize, maximize value, and focus on the processing of crude oil.

On September 1, 2017, we entered into long-term agreements with Air Liquide for the supply of hydrogen to the Tula refinery. Air Liquide will operate the existing hydrogen plant at the Tula refinery and will invest in the construction of a second plant. Air Liquide intends to provide the total supply of hydrogen required for both the existing plant and the refinery expansion projects. In December 2017, we executed the plant’s performance and stabilization tests.

Additionally, in October 2017, we began the process of selecting partners that will provide the hydrogen supply for our Madero and Cadereyta refineries. In April 2018, we entered into a long-term agreement with the German company Linde AG for the supply of hydrogen to our Madero refinery.

Gas and Aromatics

Natural Gas and Condensates

All wet natural gas production is directed to our gas processing facilities. At the end of 2017, we owned nine facilities.

The following facilities are located in the Southern region:

• Nuevo Pemex. This facility contains 13 plants that together in 2017 produced 815.5 million cubic feet per day of dry gas, 34.7 thousand barrels per day of ethane, 39.7 thousand barrels per day of liquefied gas, 16.1 thousand barrels per day of naphtha and 55.0 thousand tons of sulfur.

• Cactus. This facility contains 22 plants that together in 2017 produced 541.1 million cubic feet per day of dry gas, 26.9 thousand barrels per day of ethane, 33.8 thousand barrels per day of liquefied gas, 12.8 thousand barrels per day of naphtha and 216.1 thousand tons of sulfur.

• Ciudad Pemex. This facility contains eight plants that together in 2017 produced 612.7 million cubic feet per day of dry gas and 140.6 thousand tons of sulfur.

• La Venta. This facility contains one plant that in 2017 produced 118.1 million cubic feet of dry gas per day.

• Matapionche. This facility contains five plants that together in 2017 produced 13.6 million cubic feet per day of dry gas, 0.6 thousand barrels per day of liquefied gas, 0.2 thousand barrels per day of naphtha and 3.1 thousand tons of sulfur.

• The Morelos, Cangrejera and Pajaritos facilities form the Coatzacoalcos area gas processing complex (which we refer to as a GPC):

• Morelos. This facility contains one plant that in 2017 produced 16.8 thousand barrels per day of ethane, 15.4 thousand barrels per day of liquefied gas and 5.6 thousand barrels per day of naphtha.

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• Cangrejera. This facility contains two plants that together in 2017 produced 15.7 thousand barrels per day of ethane, 15.6 thousand barrels per day of liquefied gas and 5.7 thousand barrels per day of naphtha.

• Pajaritos. This facility contains one plant that produced 7.2 thousand barrels per day of ethane in 2017.

The following facilities are located in the Northern region:

• Burgos. This facility contains nine plants that together in 2017 produced 435.8 million cubic feet per day of dry gas, 9.5 thousand barrels per day of liquefied gas and 10.3 thousand barrels per day of naphtha.

• Poza Rica. This facility contains five plants that together in 2017 produced 106.3 million cubic feet per day of dry gas, 2.4 thousand barrels per day of liquefied gas, 0.9 thousand barrels per day of naphtha and 2.5 thousand tons of sulfur.

• Arenque. This facility contains three plants that together in 2017 produced 19.7 million cubic feet per day of dry gas and 1.8 thousand tons of sulfur.

The following tables set forth our processing capacity, as well as our total natural gas processing and production, for the five years ended December 31, 2017.

Gas and Aromatics’ Processing and Production Capacity⁽¹⁾

	Year ended December 31,
	2013		2014		2015		2016		2017
	(in millions of cubic feet per day, except where otherwise indicated)
Sweetening plants
Sour condensates(1)		144		144		144		144		144
Sour natural gas(2)(3)		4,503		4,523		4,523		4,523		4,523
Natural gas liquids recovery plants
Cryogenics		5,912		5,912		5,912		5,912		5,912
Natural gas liquids fractionating(2)(4)		569		569		569		569		569
Processing of hydrosulfuric acid		219		219		219		219		229
Aromatic compounds and derivates (Cangrejera and Independencia)(5)(6)		—		—		1,694		1,694		1,734

(1) Production capacity refers to aromatic compounds and derivatives.

(2) In thousands of barrels per day.

(3) In 2014, following a review of the sour natural gas processing capacity of the Poza Rica Complex reflecting an increase in capacity from 230 to 250 million cubic feet per day, the total installed sour natural gas processing capacity of the Pemex-Gas and Basic Petrochemicals increased from 4,503 to 4,523 million cubic feet per day.

(4) The figure for 2016 has been restated.

(5) Thousand tons per year.

(6) Since November 2015, the operation of the Methanol I and II plants, the CPQ Independencia petrochemical specialties plant and the CPQ Cangrejera aromatic compounds plants have been assigned to Pemex Industrial Transformation.

Source: Pemex BDI.

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Natural Gas, Condensates and Aromatics’ Processing and Production⁽¹⁾

	Year ended December 31,										2017 vs. 2016
	2013		2014		2015		2016		2017
	(in millions of cubic feet per day, except where otherwise indicated)										(%)
Processing
Wet gas		4,404		4,343		4,073		3,672		3,237		(11.8	)
Sour gas		3,330		3,356		3,225		2,997		2,688		(10.3	)
Sweet gas(2)		1,074		986		847		675		550		(18.5	)
Condensates(3)(6)		46		49		45		41		32		(22.0	)
Gas to natural gas liquids extraction		4,381		4,303		3,904		3,450		3,199		(7.3	)
Wet gas		4,234		4,172		3,745		3,394		3,086		(9.1	)
Reprocessing streams(4)		147		131		159		56		113		101.8
Production
Dry gas(5)		3,755		3,699		3,454		3,074		2,667		(13.2	)
Natural gas liquids(6)(7)		362		364		327		308		280		(9.1	)
Liquefied petroleum gas(6)(8)		206		205		174		159		144		(9.4	)
Ethane(6)		109		110		107		106		101		(4.7	)
Naphtha(6)		73		77		69		62		52		(16.1	)
Sulfur(9)(11)		1,029		962		858		673		551		(18.1	)
Methanol(9)		157		168		161		145		116		(20.0	)
Aromatic compounds and derivatives(9)(10)		799		1,017		1,022		940		622		(33.8	)
Others(9)(12)		588		899		535		507		302		(40.4	)

Note: Numbers may not total due to rounding.

GPC= Gas Processing Complex

(1) Excludes operations of our exploration and production segment, which produced 5,068 million cubic feet per day in 2017.

(2) Includes sweet vapor from condensates.

(3) Includes internal streams.

(4) Reprocessing of pipeline dry gas at the Pajaritos cryogenic plant.

(5) Includes ethane reinjected into the natural gas stream.

(6) In thousands of barrels per day.

(7) Includes stabilized condensates, reprocessing streams from the Cangrejera petrochemical complex and other streams for fractionating.

(8) Includes production from GPC, refineries and transfers from Pemex Exploration and Production.

(9) In thousands of tons.

(10) Includes aromine 100, benzene, styrene, toluene, ethylbenzene, fluxoil, high octane hydrocarbon and xylenes.

(11) Production of gas processing GPCs and refineries.

(12) Includes butanes, petrochemical specialties, pentanes, hexane, hydrogen, BTX liquids, isopentanes and petroleum products, naphtha gas, petrol octane base and heavy naphtha.

Source: Pemex BDI.

Domestic consumption of dry gas totaled 2,623.0 million cubic feet per day in 2017, a 21.6% decrease from the 2016 domestic consumption of 3,347.3 million cubic feet per day.

We import dry gas to satisfy shortfalls in our production and to meet demand in areas of northern Mexico that, due to their distance from the fields, can be supplied more efficiently by importing natural gas from the United States. In 2017, we imported 1,766.0 million cubic feet per day of natural gas, a decrease of 8.7% from the 1,933.9 million cubic feet per day imported in 2016, mainly due to the fact the CFE is directly importing natural gas to supply its power generation plants. The total amount of natural gas imported per day in 2017 included 26.3 million cubic feet of liquefied natural gas imported through Manzanillo.

We process sour and sweet condensates from our exploration and production segment in order to obtain stabilized natural gas liquids and also recover liquid hydrocarbons obtained from the processing of sweet natural gas. In addition, we obtain natural gas liquids from internal streams and liquid hydrocarbons condensed in sour wet gas pipelines. Our production of natural gas liquids, including stabilized condensates, reprocessing and other fractionating streams, decreased by 9.1% from 308 thousand barrels per day in 2016 to 280 thousand barrels per day in 2017.

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We process sour condensates, which have a higher sulfur content, to produce stabilized sweet condensates. The volume of sour condensates we processed from our exploration and production segment and internal streams of our gas and aromatic compound sub-segment totaled 32 thousand barrels per day in 2017, a 21.9% decrease from the 41 thousand barrels per day processed in 2016. We also process sweet condensates at our Burgos facilities to produce light and heavy natural gasoline.

The production of aromatic compounds and derivatives decreased 33.8%, from 940.2 thousand tons in 2016 to 622.0 thousand tons in 2017 due to operational challenges in the continuous catalyst regeneration and styrene plants throughout the year.

Natural Gas Supply Strategy

On August 13, 2013, we and the Mexican Government prepared a strategy to address domestic natural gas shortages in the short-, medium- and long-term. On January 1, 2016, as part of the opening of the natural gas market, we transferred certain of our transportation assets to CENAGAS in a step towards that goal.

Over the five years ended December 31, 2017, the value of our domestic sales was distributed as follows:

Value of Gas and Aromatics’ Domestic Sales⁽¹⁾

	Year ended December 31,										2017 vs. 2016
	2013		2014		2015		2016		2017
	(in millions of pesos)(2)										(%)
Natural gas	Ps.	68,128.7	Ps.	78,666.4	Ps.	53,037.3	Ps.	67,536.5	Ps.	74,287.7		10.0
Liquefied petroleum gas		71,728.9		78,258.9		78,194.0		50,179.8		49,137.3		(2.1	)
Ethane(3)		32.3		283.6		310.7		1,284.7		2,989.7		132.7
Heptane		62.7		39.1		1.0		—		0.9		—
Propane		70.3		92.4		57.6		73.8		111.6		51.2
Light naphtha		—		2.8		39.7		84.5		158.8		87.9
Heavy naphtha		4.4		15.7		191.0		404.8		429.3		6.1
Sulfur		659.6		795.9		926.1		585.7		540.2		(7.8	)
Methanol		733.9		775.5		748.4		625.1		806.9		29.1
Aromatic compounds and derivatives(4)		3,641.4		4,427.5		3,479.4		2,122.1		1,673.1		(21.2	)
Others(5)		347.7		658.9		400.2		261.4		309.5		18.4
Total	Ps.	145,409.9	Ps.	164,016.7	Ps.	137,385.4	Ps	.123,158.5	Ps.	130,445.0		5.9

Note: Numbers may not total due to rounding.

(1) Excludes value added tax.

(2) Figures are stated in nominal pesos.

(3) Ethane sales to Petroquímica Mexicana de Vinilo S.A. de C.V. began in October 2013. In January 2016, we began the supply of ethane to Braskem IDESA.

(4) Includes aromine 100, benzene, styrene, toluene, xylene.

(5) Includes petrochemical specialties, hydrogen, isopropane, heptane, hexane, pentane and naphtha gas.

Source: Pemex BDI.

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The volume of our domestic sales of gas and aromatics for the five-year period ended December 31, 2016 was distributed as follows:

Volume of Gas and Aromatics’ Domestic Sales

	Year ended December 31,										2017 vs. 2016
	2013		2014		2015		2016		2017
	(in thousands of barrels per day, except where otherwise indicated)										(%)
Natural gas(1)		3,463.5		3,451.2		3,246.8		3,347.3		2,623.0		(21.6	)
Liquefied petroleum gas(2)		284.3		282.1		278.8		202.1		171.3		(15.2	)
Ethane(3)		0.8		5.8		8.8		30.5		57.7		89.2
Heptane		3.9		3.0		0.1		—		0.1		—
Propane		9.3		9.7		10.1		11.3		11.3		—
Heavy naphtha(4)		0.4		1.5		29.9		64.3		56.2		(12.6	)
Light naphtha(4)		—		0.3		6.2		13.3		19.9		49.6
Sulfur(4)		520.7		655.3		572.7		580.5		529.9		(8.7	)
Methanol(4)		100.1		110.9		112.0		111.3		100.8		(9.4	)
Aromatic compounds and derivatives(4)(5)		197.4		246.8		240.0		155.1		111.3		(28.2	)
Others(4)(6)		25.9		51.3		40.6		29.6		28.2		(4.7	)
Total		4,606.4		4,817.8		4,545.9		4,545.3		3,707.5		(18.4	)

Note: Numbers may not total due to rounding.

(1) In millions of cubic feet per day.

(2) In thousands of barrels per day.

(3) Ethane sales to Petroquímica Mexicana de Vinilo S.A. de C.V. began in October 2013.

(4) In thousands of tons per year.

(5) Includes aromine 100, benzene, styrene, toluene, ethylbenzene, fluxoil and xylene.

(6) Includes petrochemical specialties, hydrogen, isopropane, heptane, hexane, pentane and naphtha gas.

Source: Pemex BDI.

In 2017, the value of our domestic sales increased by 5.9%, as compared to 2016, to Ps. 130,445.0 million, primarily due to an increase in the average price of natural gas.

Domestic sales of LPG decreased by 15.2%, as compared to 2016, to 171.3 thousand barrels per day, primarily due to part of market demand being filled by foreign imports of LPG by private companies.

Domestic sales of natural gas decreased by 21.6%, as compared to 2016, to 2,623.0 million cubic feet per day due to decreasing domestic demand in the electric sector. Demand in the electric sector decreased by 39.7% because the CFE, which uses electric power to supply its power generation plants, directly imported natural gas from abroad in order to supply its plants. Domestic sales of sulfur decreased by 8.7%, as compared to 2016, to 529.9 thousand tons due to a decrease in production in our refineries and complex gas processors. Domestic sales of aromatic compounds and derivatives decreased by 28.2%, as compared to 2016, to 111.3 thousand tons due to decreased production as a result of maintenance at our plants.

Subsidiaries of Pemex Industrial Transformation

Pemex Industrial Transformation conducts certain management, real estate and distribution activities through its subsidiaries and through certain joint ventures. The following table lists its subsidiaries, their principal operating activities and Pemex Industrial Transformation’s ownership interest as of December 31, 2017.

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Subsidiaries of Pemex Industrial Transformation⁽¹⁾

Subsidiary	Principal Activity	Ownership Interest (%)
Mex Gas Internacional, S.L.(2)	Holding company		100.00
Pasco International, Ltd.(3)	Holding company		100.00
Terrenos para Industrias, S.A.	Real estate holding company		100.00

(1) As of December 31, 2017.

(2) Mex Gas Internacional, S.L. is the only subsidiary of Pemex Industrial Transformation that is a consolidated subsidiary company. See Note 4 to our consolidated financial statements included herein.

(3) Pasco International, Ltd. was liquidated on May 31, 2017.

Source: Pemex Industrial Transformation

The following table lists Pemex Industrial Transformation’s joint ventures, its principal operating activities and Pemex Industrial Transformation’s ownership interests as of December 31, 2017.

Joint Ventures of Pemex Industrial Transformation⁽¹⁾

Subsidiary	Principal Activity	Ownership Interest (%)
CH4 Energía, S.A. de C.V(1)	Gas trading		50.00
Ductos y Energéticos del Norte, S. de R.L. de C.V.(2)	Holding company		50.00

⁽¹⁾  In December 2017, CH4 Energía, S.A. de C.V., was transferred to Mex Gas Internacional, S.L., as a part of a restructuring of the Pemex Industrial Transformation subsidiary companies.

⁽²⁾  The share of Pemex Industrial Transformation in Ductos y Energéticos del Norte was ceded to IEnova Pipelines, S. de R.L. de C.V., on November 16, 2017. See “—Divestitures” below.

Source: Pemex Industrial Transformation

Divestitures

On July 31, 2015, we announced the divestiture of our 50% ownership interest in the Gasoductos de Chihuahua, S. de R.L. de C.V. (Gasoductos de Chihuahua) joint venture with Infraestructura Energética Nova, S.A.B. de C.V. (IEnova). IEnova shareholders approved the transaction in September 2015. On September 15, 2016, Mexico’s Comisión Federal de Competencia Económica (Federal Economic Competition Commission or COFECE) approved the proposed direct sale to IEnova as it was structured, which included a competitive bidding process with respect to Gasoducto San Fernando and LPG Ducto TDF. The initial divestiture did not include Gasoductos de Chihuahua’s subsidiary company, Ductos y Energéticos del Norte, S. de R.L. de C.V., so Pemex Industrial Transformation retained a 50% share participation. On September 28, 2016, we announced the divestiture of our interest in Gasoductos de Chihuahua. IEnova’s interest in the company increased from 50% to 100%. The transaction was valued at U.S. $1,143.8 million.

On October 6, 2017, we announced the divestiture of our 50% ownership interest in the Ductos y Energéticos del Norte, S. de R.L. de C.V., joint venture. This divestiture included our 25% ownership interest in the Ramones II Norte gas pipeline. On November 16, 2017, the divestiture took place in favor of IEnova Pipelines, S. de R.L. de C.V. The transaction was valued at U.S.$260 million, which is within the range of valuations of comparable companies and past transactions in the hydrocarbon transporation and storage sector and which we believe reflected the fair market value. We expect the proceeds from this divestiture will contribute to improving our financial profile and decrease our need to raise capital in the debt markets.

Pricing Decrees

The energy reform provides for fuel price liberalization, which began in early 2017 and was completed by the end of that year. Even though prices have been fully liberalized, the CRE reserves the right to intervene.

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Therefore, our sales prices continue to be subject to potential future regulations by the CRE , until the Comisión Federal de Competencia Económica (Federal Economic Competition Commission) determines that there is effective competition in the wholesale market.

Prior to the energy reform, the Mexican Government determined natural gas prices for domestic sales, which were calculated in accordance with directives issued by the CRE on July 20, 2009 and the related Resolutions of December 20, 2010, March 3, 2011, December 20, 2012, January 17, 2013, March 21, 2013 and December 3, 2013, by which the CRE approved and issued a temporary methodology for determining the maximum prices of natural gas of first-hand sales. On February 15, 2016, the CRE issued a new methodology which, effective March 1, 2016, determined the maximum first-hand sales price of natural gas. These prices aimed to reflect natural gas opportunity costs and competitive conditions in international markets and at the point of sale.

As of July 1, 2017, the CRE will permit third-party participants to enter the gasoline and diesel market and has authorized the permanent regime of first-hand sales of natural gas. This permanent regime allows us to sell natural gas under two separate pricing mechanisms: (1) the first hand sale price, wherein we may sell natural gas directly to customers without additional transportation or services and (2) the full marketing price, wherein we may charge a higher price that includes transportation and services costs associated with the commercialization of natural gas.

Since 2003, price control mechanisms for LPG have been implemented through governmental decrees.

In January 2010, the Mexican Government issued a decree establishing the maximum weighted average end-user price of LPG before taxes of Ps. 8.08 per kilogram. Subsequently, as of February 2010, the Mexican Government established monthly maximum price increases in cents per kilogram before taxes, as follows:

Period	Mexican Cents per Kilogram
February 2010 to July 2011		5
August to November 2011		7
December 2011		8
January 2012 to October 2013		7
November to December 2013		9
January to December 2014		9	*
January 2015		23	*
January 2016		34

* On January 1, 2014 and 2015, pursuant to the IEPS Tax on Fossil Fuels, a price increase of 12 and 13 Mexican cents per kilogram, respectively, went into effect in addition to the monthly price increase of nine Mexican cents per kilogram in 2014 and ten Mexican cents per kilogram in 2015; this resulted in a total increase of 23 Mexican cents per kilogram in 2015. The ten Mexican cent per kilogram increase in January 2015 was a one-time increase for the year, and no further monthly increases were established for the remainder of 2015.

Beginning in August 2014, the methodology for calculating end-user prices was modified from weighted average prices to simple average prices.

On January 1, 2016, the Mexican Government issued a decree establishing a one-time price increase of 34 Mexican cents per kilogram, which was effective until August 16, 2016. In addition, the IEPS Tax on Fossil Fuels of 13 Mexican cents per kilogram was in effect until February 29, 2016, at which point the Mexican Government eliminated the periodic price increases. On August 17, 2016, the Mexican Government authorized an end user discount of 9.97%, which was effective until December 31, 2016.

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Since January 1, 2017, we have sold natural gas in accordance with the new methodology authorized by CRE for determining the first hand sales price at the point of delivery, and all end user prices are freely determined by the market.

As of January 1, 2018, the IEPS Tax on Fossil Fuels is 14 Mexican cents per kilogram.

The Mexican Government could modify these price controls or impose additional price controls in the future. See “Item 3—Key Information—Risk Factors—Risk Factors Related to our Relationship with the Mexican Government—The Mexican Government has historically imposed price controls in the domestic market on our products.”

Natural Gas Hedging Operations

We offer, as a value-added service, various hedging contracts to our domestic customers to protect them against fluctuations in the prices of natural gas. For information on hedging contracts offered to natural gas domestic customers, see “Item 11—Quantitative and Qualitative Disclosures about Market Risk.”

Gas and Aromatics Capital Expenditures

Our gas and aromatics business invested Ps. 2,587 million in capital expenditures in 2017 and has budgeted Ps. 3,984 million in capital expenditures for 2018.

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The following table sets forth our gas and aromatics business’ capital expenditures, excluding non-capitalizable maintenance, for each of the three years ended December 31, 2017, and the budget for 2018. Capital expenditure amounts are derived from our budgetary records, which are prepared on a cash basis. Accordingly, these capital expenditure amounts do not correspond to capital expenditure amounts included in our consolidated financial statements prepared in accordance with IFRS.

Gas and Aromatics’ Capital Expenditures

	Year ended December 31,(1)						Budget 2018(2)
	2015		2016		2017
	(in millions of pesos)(3)
Gas and Aromatics
Modernization of Transportation Areas of GPCs	Ps.	534	Ps.	482	Ps.	239	Ps.	605
Modernization of Measuring, Control and Security Systems of GPCs		463		481		—		—
Refurbishment and Modernization of Natural Gas Turbocompressors of the Cryogenic Plants at Nuevo Pemex GPC		143		257		41		—
Modernization and Rehabilitation of Facilities of the Supply and Water Treatment System at Nuevo Pemex GPC		344		255		216		6
Integral Project of Electric Reliability at GPCs		474		177		22		—
Adaptation of Fractionation Plants and Conversion of the Liquids Sweetener at Nuevo Pemex GPC		320		174		271		23
Refurbishment of Refrigerating and Ethane Turbocompressors of Fractionating Plants at Nuevo Pemex GPC		199		119		—		—
Integral Maintenance of Gas Sweetening Plants 1, 2, 3 and 12 at Cactus GPC		109		116		64		97
Conservation and Modernization of the Storage Area at Coatzacoalcos Area GPC		208		88		32		134
Security Requirements for Improvement of Operational Reliability of the GPCs		211		87		31		39
Conditioning of the Venting Systems at Cactus GPC		109		75		147		131
Conservation of Processing Capacity at Nuevo Pemex GPC		180		70		—		—
Conservation of Operational Reliability at Ciudad Pemex GPC		196		31		6		—
Conditioning of Facilities for Ethane Supply at Cactus GPC		234		21		5		—
Integral Facilities Maintenance at Cactus GPC		137		21		—		—
Others		1,793		992		1,514		2,949
Total	Ps.	5,654	Ps.	3,446	Ps.	2,587	Ps.	3,984

Notes: Numbers may not total due to rounding.

          GPC = Gas Processing Complex.

          PC = Petrochemical Complex.

(1) Amounts based on cash basis method of accounting.

(2) Budget presented to the Board of Directors of Petróleos Mexicanos on March 5, 2018.

(3) Figures are stated in nominal pesos.

Source: Petróleos Mexicanos.

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Ethane Supply Contract

On February 19, 2010, we entered into a contract to supply 66,000 barrels per day of ethane to the Etileno XXI project, a petrochemical complex in Nanchital, Veracruz that will produce ethylene and polyethylene. The Etileno XXI project is being developed and will be owned and operated by Braskem-IDESA, a Brazilian-Mexican consortium. In order to meet the obligations of this contract, we made adjustments to the infrastructure of our gas processing plants in the Ciudad Pemex, Nuevo Pemex and Cactus. Additional ethane will be transported from the GPCs located in Tabasco, in southeastern Mexico, to Coatzacoalcos, Veracruz. This contract provides for “take or pay—delivery or pay” obligations for the parties, and thus, in case of breach of our supply obligation, we are subject to the payment of liquidated damages. In the event of termination as a consequence of our material default under the ethane supply contract, we may be obligated to pay to the other parties involved in the project an amount equal to the termination value of this project (the value of which is determined pursuant to the contract and takes into consideration, among other factors, the outstanding debt of the project and the amount invested in the project at such time). The Etileno XXI project commenced operations on March 18, 2016. By December 31, 2016, we had supplied 562.8 million cubic meters of ethane for a total of Ps. 1,426 million. Also as of December 31, 2016, construction of the pipeline to transport ethane from the gas processing plants located in Tabasco, in Southeastern Mexico, to Coatzacoalcos, Veracurz, was complete.    

Fertilizers

Our fertilizers segment operates through the productive state-owned subsidiary Pemex Fertilizers, produces ammonia and carbon dioxide and integrates the ammonia production chain up to the point of sale of fertilizers. Our strategy for the fertilizers segment focuses on (1) increasing the economic value of the segment by generating diverse investment opportunities in the agricultural sector in Mexico and (2) ensuring a reliable supply of natural gas for our plants through a long-term contract that sustains operations for four ammonia plants.

Certain of the plants in Cosoleacaque are showing signs of deterioration due to a lack of proper maintenance. However, we expect to have three plants in operating condition by the second quarter of 2018.

Capacity

At the end of 2017, we owned four petrochemical plants, three of which are in operation, for the production of ammonia. We had a total production capacity of 1,440 thousand tons of ammonia per year in 2017.

The total production capacity of our operating plants for the last three years was distributed among our facilities as set forth below:

Fertilizers Segment’s Total Capacity

	Year ended December 31,
Petrochemical Complexes	2015		2016		2017
			(thousands of tons)
Cosoleacaque (ammonia)		1,440		1,440		1,440

Source: Pemex Fertilizers.

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Production

The following table summarizes the annual production of our fertilizers segment for the three years ended December 31, 2017.

Fertilizers Segment’s Production

	Year ended December 31,
	2015		2016		2017		2017 vs. 2016
			(thousands of tons)				(%)
Methane Derivatives
Ammonia		575		533		500		(6.2	)
Carbon dioxide		830		786		844		7.4
Total		1,406		1,319		1,343		1.8

Note: Numbers may not total due to rounding.

Source: Pemex BDI.

Total annual production of methane derivatives in 2017 increased 1.8% from 1,319 thousand tons in 2016 to 1,343 thousand tons in 2017, mainly due to increased production of carbon dioxide.

In 2017 we produced 500 thousand tons of ammonia, which represents a decrease of 6.2% as compared to 533 thousand tons produced in 2016. In 2017, we produced 844 thousand tons of carbon dioxide, a by-product of the production process, which represents a 7.4% increase as compared to 2016.

Sales of Fertilizers

The following table sets forth the value of our domestic sales for the three years ended December 31, 2017:

Value of Fertilizers Segment’s Domestic Sales⁽¹⁾

	Year ended December 31,
	2015		2016		2017		2017 vs. 2016
	(in millions of pesos)(2)						(%)
Methane Derivatives
Ammonia		Ps. 4,414.6		Ps. 4,593.1		Ps. 4,676.5		1.8
Carbon dioxide		69.9		90.2		109.1		21.0
Urea (resale)		46.5		6.9		—		(100	)
Total		Ps. 4,531.0		Ps. 4,690.1		Ps. 4,785.7		2.0

Note: Numbers may not total due to rounding.

(1) Excludes value added tax.

(2) Figures are stated in nominal pesos.

Source: Pemex BDI.

In 2017 the value of domestic sales in our fertilizers segment increased by 2.0%, from Ps. 4,690.1 million in 2016 to Ps. 4,785.7 million in 2017, primarily due to an increase in the volume of sales of ammonia, as presented in more detail below.

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Volume of sales

The following table sets forth the value of our domestic sales for the three years ended December 31, 2017:

Volume of Fertilizers Segment’s Domestic Sales

	Year ended December 31,
	2015		2016		2017		2017 vs. 2016
	(thousands of tons)						(%)
Methane Derivatives
Ammonia		643.4		752.8		760.4		1.0
Carbon dioxide		166.0		179.7		207.6		15.5
Urea (resale)		10.0		1.7		—		(100	)
Total		819.5		934.3		968.0		3.6

Note: Numbers may not total due to rounding.

Source: Pemex BDI.

Fertilizers Capital Expenditures

Our fertilizers segment invested Ps. 264 million in capital expenditures in 2017 and has budgeted Ps. 444 million in capital expenditures for 2018. The following table sets forth our fertilizers segment’s capital expenditures, excluding non-capitalizable maintenance, for each of the three years ended December 1, 2017, and the budget for 2018. Capital expenditure amounts are derived from our budgetary records, which are prepared on a cash basis. Accordingly, these capital expenditure amounts do not correspond to capital expenditure amounts included in our consolidated financial statements prepared in accordance with IFRS.

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Fertilizers’ Capital Expenditures

	Year ended December 31,(1)						Budget
	2015		2016		2017		2018(2)
			(in millions of pesos)(3)
Fertilizers
Rehabilitation of Ammonia Plant IV and Integration and Auxiliary Services for Cosoleacaque PC	Ps.	791	Ps.	295	Ps.	102	Ps.	68
Efficiency in Storage and Distribution of Pemex-Petrochemicals		—		45		38		127
Maintaining the Production Capacity of Ammonia Plant VII and its Auxiliary Services at Cosoleacaque PC		101		18		5		3
Maintaining the Production Capacity of Ammonia Plant VI at Cosoleacaque PC		97		16		—		3
Safety and Environmental Protection, Derived from Observations and Regulations II in Cosoleacaque PC		43		5		—		—
Rehabilitation of Primary Reformers and Auxiliary Ammonia Plant VI and VII of Cosoleacaque PC		—		—		75		90
Others		12		—		45		154
Total	Ps.	1,044	Ps.	379	Ps.	264	Ps.	444

Notes: Numbers may not total due to rounding.

PC = Petrochemical Complex.

(1) Amounts based on cash basis method of accounting.

(2) Budget presented to the Board of Directors of Petróleos Mexicanos on March 5, 2018.

(3) Figures are stated in nominal pesos.

Source: Petróleos Mexicanos..

Pajaritos Petrochemical Complex

In 2014, we acquired a closed fertilizer production facility located in Pajaritos, Veracruz, Mexico, which we are currently renovating. The renovation of the facility involves restoring operations of our rotating, static and mechanical equipment, building a carbon dioxide compressor station, as well as other auxiliary projects and is expected to be finalized during the first quarter of 2018. By the second quarter of 2018, and assuming the sufficient supply of ammonia from Cosoleacaque, we expect to have a production capacity of 90 thousand tons of urea per month.

Acquisition of Fertinal

On January 28, 2016, PMX Fertilizantes Pacífico, S.A. de C.V., one of our subsidiaries, acquired 99.99% of the outstanding shares of Fertinal, for a total purchase price of Ps. 4,322.8 million. Before this acquisition, Fertinal experienced a prolonged period without any investment, as well as problems with its cash flows. In July 2016, we added U.S.$120 million for working capital needs and capital expenditures in order to improve Fertinal’s production capacity. By the fourth quarter of 2017, Fertinal’s financial position had improved significantly and it has seen improved performance on its production ratios as of the date of this annual report.

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Fertinal’s total production capacity for the years ended December 31, 2016 and 2017 is as set forth below:

Fertinals Segment’s Total Capacity

	Year ended December 31,
	2016		2017
	(thousands of tons)
Nitrate and phosphates		1,299		1,420

Source: Fertinal Group

Fertinal’s total production for the years ended December 31, 2016 and 2017 is set forth below:

Fertinals Segment’s Production

	Year ended December 31,
	2016		2017		2017 vs. 2016
	(thousands of tons)				%
Phosphates		682.0		763.9		12.0
Nitrate		187.3		220.8		18.0
Others		5.7		3.5		(38.6	)
Total		875.0		988.2		13.0

Source: Fertinal Group

The following table sets forth the value of Fertinal’s domestic sales for the years ended December 31, 2016 and 2017:

Value of Fertinal’s Domestic Sales⁽¹⁾

	Year ended December 31,
	2016		2017		2017 vs. 2016
	(in millions in pesos)(2)				%
Phosphates		Ps. 1,430.9		Ps. 1,717.5		20.0
Nitrogenated		1,154.3		1,099.1		(4.8	)
Others		61.4		148.8		142.3
Total		Ps. 2,646.6		Ps. 2,965.5		12.0

Note: Numbers may not total due to rounding.

(1) Excludes value added tax.

(2) Figures are stated in nominal pesos.

Source: Fertinal Group.

We intend to incorporate Fertinal into the gas ammonia solid fertilizers value chain in order to offer a wide range of fertilizers and to cover approximately 50% of the domestic market. We are also assessing the possibility of selling this integrated business in the future.

On February 2, 2017, P.M.I. Holding B.V. (PMI-HBV) converted its long-term debt securities with Fertinal into 2,313,600,000 Fertinal shares, which represents 38.2% of the total shares. There was no effect on cash flow as a result of this transaction.

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On June 14, 2017, PMI-NASA and P.M.I. Infraestructura de Desarrollo, S.A. de C.V. (PMI-ID) transferred 100% of their ownership interest in Pro-Agroindustria, S.A. de C.V. to PMX Fertilizantes Holding, S.A. de C.V. (PMX-H) and PMX Fertilizantes Pacífico, S.A. de C.V. (PMX-P) as follows: PMI-NASA transferred 1% of the shares to PMX-H and PMI-ID transferred 99% of the shares to PMX-P. On the same date, PMI-HBV transferred 100% of its stock in Fertinal to PMX-P. There was no effect on cash flow from these transfers, which were performed with the authorization and approval of the respective Boards of Directors and in accordance with the Ley de Petróleos Mexicanos.

Ethylene

Our ethylene segment operates through the productive state-owned subsidiary Pemex Ethylene and takes advantage of the integration of the ethylene production chain by manufacturing various petrochemical products. Our ethylene segment manufactures various petrochemical products, including:

• ethane derivatives, such as ethylene, polyethylenes, ethylene oxide and glycols;

• propylene and derivatives; and

• others such as oxygen, nitrogen, hydrogen, butadiene and CPDI, among other products.

Capacity

Total production capacity of our operating plants for the last three years was distributed among our facilities as set forth below:

Ethylene Segment’s Production Capacity

	Year ended December 31,
	2015		2016		2017
	(in thousands of tons)
Petrochemical Facility
Cangrejera(1)		1,321.3		1,321.3		1,321.3
Morelos		2,277.2		2,277.2		2,277.2
Total		3,598.5		3,598.5		3,598.5

Notes: Numbers may not total due to rounding.

(1) Our ethylene segment’s capacity in Cangrejera does not include products from the aromatics and derivatives chain. These products belong to Pemex Industrial Transformation.

Source: Pemex Ethylene.

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Production

The following table sets forth our ethylene segment’s production for the three years ended December 31, 2017:

Ethylene Segment’s Production⁽¹⁾

	Year ended December 31,
	2015		2016		2017		2017 vs. 2016
	(in thousands of tons)						(%)
Ethane derivatives		1,992.8		1,690.7		1,274.1		(24.6	)
Propylene and derivatives		66.0		42.8		12.9		(69.9	)
Others		910.9		795.2		597.0		(24.9	)
Total(1)		2,969.7		2,528.7		1,884.0		(25.5	)

Note: Numbers may not total due to rounding.

(1) Figures include petrochemical products used as raw material to produce other petrochemicals.

Source: Pemex BDI.

In 2017, our total production in the ethylene segment decreased 25.5%, from 2,528.7 thousand tons in 2016 to 1,884.0 thousand tons in 2017, primarily due to a decrease in the production of ethylene and derivatives of ethylene (high and low density polyethylene, ethylene oxide and glycols), which was the result of a 28% decrease in the supply of raw materials, including ethane gas, during 2017, and the closure of our acrylonitrile plant.

Domestic Sales

The following table sets forth our ethylene segment’s domestic sales for the three years ended December 31, 2017.

Value of Ethylene Segment’s Domestic Sales⁽¹⁾

	Year ended December 31,
	2015		2016		2017		2017 vs. 2016
	(in millions of pesos)(2)						(%)
Ethane derivatives		Ps.15,649.1		Ps. 14,539.4		Ps. 12,252,7		(15.7	)
Propylene and derivatives		1,156.5		788.3		340.7		(56.8	)
Others		104.0		64.8		28.3		(56.3	)
Total		Ps.16,909.6		Ps. 15,392.5		Ps. 12,621.7		(18.0	)

Note: Numbers may not total due to rounding.

(1) Excludes value added tax.

(2) Figures are stated in nominal pesos.

Source: Pemex BDI.

In 2017, our domestic sales decreased by 18.0% from Ps. 15,392.5 million in 2016 to Ps. 12,621.7 million in 2017. This decrease was primarily due to lower production of polyethylenes and ethylene oxid as a result of a decrease in the supply of raw materials, including ethane, and the closure of our acrylonitrile plant at the Morelos Petrochemical complex.

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On July 7, 2017 Pemex Ethylene successfully concluded an electronic auction to allocate the supply of ethylene oxide. Ten domestic ethylene oxide companies participated in the auction, which resulted in all of the available volume being placed at a market price that was a higher than the historical price of ethylene oxide.

Sales to other Subsidiary Entities

The following table sets forth the intercompany sales of petrochemical products for the three years ended December 31, 2017.

Ethylene Segment’s Intercompany Sales⁽¹⁾

	Year ended December 31,
	2015		2016		2017		2017 vs. 2016
			(in millions of pesos)(2)				(%)
Ethane and derivatives		Ps. 82.1		Ps.107.9		Ps. —		(100	)
Others		86.9		373.7		284.2		(23.9	)
Total		Ps.169.0		Ps. 481.6		Ps. 284.2		(41.0	)

Note: Numbers may not total due to rounding.

(1) Excludes value added tax.

(2) Figures are stated in nominal pesos.

Source: Pemex Ethylene.

In 2017, our intercompany sales decreased by 41.0%, from Ps. 481.6 million in 2016 to Ps. 284.2 million in 2017. This decrease was primarily due to a decrease in the volume of sales of nitrogen, pyrolysis gasoline and ethylene in 2017, as compared to 2016, mainly due to a decrease in the supply of raw materials, including ethane gas.

Ethylene Capital Expenditures

Our ethylene segment invested Ps. 618 million in capital expenditures in 2017, and has budgeted Ps. 1,786 million for capital expenditures in 2018.

The following table sets forth our ethylene segment’s capital expenditures, excluding non-capitalizable maintenance, for each of the three years ended December 31, 2015, 2016 and 2017, and the budget for 2018. Capital expenditure amounts are derived from our budgetary records, which are prepared on a cash basis. Accordingly, these capital expenditure amounts do not correspond to capital expenditure amounts included in our consolidated financial statements prepared in accordance with IFRS.

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Ethylene’s Capital Expenditures

	Year ended December 31,(1)						Budget 2018(2)
	2015		2016		2017
			(in millions of pesos)(3)
Ethylene
Maintaining the Production Capacity of Ethylene Plant 2013-2015 at Morelos PC		Ps. 93		Ps. 122		Ps. —		Ps. —
Modernization and Optimization of Auxiliary Services Infrastructure I at Morelos PC		5		105		74		52
Modernization of Fire Protection Network at Cangrejera PC		102		71		68		146
Safety and Environmental Protection Based on Observations and Regulations IV at Morelos PC		114		43		1		11
Maintaining Production Capacity of the Low Density Polyethylene Plant		112		40		67		—
Maintaining the Production Capacity of Ethane Derivatives Chain II at Morelos PC		87		38		1		—
Maintaining the Production Capacity of Auxiliary Services II		78		27		16		—
Maintaining the production capacity of ethylene oxide plant 2015-2017 at Morelos PC		1		23		49		144
Maintaining the Production Capacity of Auxiliary Services III		59		17		8		35
Maintaining the Production Capacity of Auxiliary Services at Morelos PC		48		17		4		153
Maintaining the Production Capacity of the Ethane Derivatives Chain III at Morelos PC		54		8		1		—
Maintaining the Production Capacity of the Mitsui plant 2015-2017 at Morelos PC		4		8		14		15
Maintaining the Production Capacity of the Swing Plant 2015-2017 at Morelos PC		7		6		16		258
Modernization and Expansion of Production Capacity of Ethane Derivatives Chain I at Morelos PC		402		3		—		5
Others		426		219		299		968
Total		Ps. 1,869		Ps. 746		Ps. 618		Ps. 1,786

Notes: Numbers may not total due to rounding.

         PC = Petrochemical Complex.

(1) Amounts based on cash basis method of accounting.

(2) Budget presented to the Board of Directors of Petróleos Mexicanos on March 5, 2018.

(3) Figures are stated in nominal pesos.

Source: Petróleos Mexicanos.

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Joint Venture with Mexichem

On December 20, 2017, Mexichem, S.A.B. de C.V. (Mexichem) announced that the Board of Directors of its joint venture, Petroquímica Mexicana de Vinilo S.A. of C.V. (PMV), a co-investment with PPQ Cadena Productiva S.L., a subsidiary of Pemex Ethylene, and of Mexichem’s Vinyl Business Group, has decided not to rebuild its Vinyl Monochloride (VCM) production capacity. Therefore, the joint venture’s VCM production, and the assets and liabilities associated with ethylene production and auxiliary services associated with VCM and ethylene will be classified as discontinued operations.

This represents the exit of PMV from the VCM and ethylene businesses in Mexico. Mexichem and Pemex Ethylene will continue to evaluate the possibility of investing in the future, jointly or separately, through PMV or another vehicle, in businesses related to VMC and ethylene production or otherwise. Moreover, the chlorine-soda plant will continue to be operated by PMV, and therefore the alliance between Pemex Ethylene and Mexichem will remain in place.

Drilling and Services

Our drilling and services segment operates through the productive state-owned subsidiary Pemex Drilling and Services and provides drilling, completion, work-over and other services for wells in offshore and onshore fields. During 2017, this segment mainly provided drilling services to Pemex Exploration and Production, but also provided services to third-party clients such as CONAGUA, Marinsa, Latina, Fieldwood and Key Energy.

As a result of our corporate reorganization, for the year ended December 31, 2015, we have presented operating results for our drilling and services segment together with results for our exploration and production segment. We have summarized some of these results below. For additional results for this segment, please see “—Exploration and Production—Exploration and Drilling” above in this Item 4. Operating results for these segments are presented separately for periods beginning January 1, 2016. When reviewing these results, please note that our exploration and production segment receives drilling services not only from our drilling and services segment but also from third parties. Accordingly, the amounts presented above under drilling activity do not relate only to services provided by our drilling and services segment. For a detailed description of the financial results of each segment, see our consolidated financial statements included herein.

During 2017, we drilled 52 wells, 13 onshore and 39 offshore; completed 54 wells, 11 onshore and 43 offshore; and made 496 workovers, 393 onshore and 103 offshore. Of the wells completed, one was for CONAGUA. Those services were performed with an average of 47 drilling and workover rigs, 20 terrestrial and 27 marine, including both owned and leased equipment. Moreover, we conducted 20,658 well services in 2017, of which 48% were wireline operations, 30% were cementing jobs, 18% were logging operations and perforations and 4% were coiled tubing operations. In addition, we provided drilling and services to external customers such as CONAGUA, Marinsa, Latina, Fieldwood and Key Energy.

Given the current state of the oil and gas industry and relatively low global oil prices, the demand for well drilling and services decreased in 2017 by approximately 35% as compared to 2016. In 2018, we expect well interventions to increase by approximately 28% compared to 2017, and we expect to operate an average of 50 rigs—23 land and 27 marine—including both owned and leased equipment, which represents a 6% increase as compared to 2017. Of these, we expect that 21 land and 5 marine will be rigs we own, which is a 24% decrease as compared to 2017.

In 2017, in accordance with our “Programa de modernización de la infraestructura de perforación” (Drilling Infrastructure Modernization Program), we carried out the modernization of two drilling land rigs of 2000 HP for an amount of U.S. $16.6 million. In addition, we are evaluating the acquisition of two workover land rigs of 200-350 HP.

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Drilling and Services Capital Expenditures

Our drilling and services segment invested Ps. 1,550 million on capital expenditures in 2017 and has budgeted Ps. 1,434 million for capital expenditures in 2018.

The following table sets forth our drilling and services segment’s capital expenditures, excluding non-capitalizable maintenance, for each of the three years ended December 31, 2015, 2016 and 2017, and the budget for 2018. Capital expenditure amounts are derived from our budgetary records, which are prepared on a cash basis. Accordingly, these capital expenditure amounts do not correspond to capital expenditure amounts included in our consolidated financial statements prepared in accordance with IFRS.

Drilling and Services’ Capital Expenditures

	Year ended December 31,(1)						Budget 2018(3)
	2015(2)		2016		2017
			(in millions of pesos)(4)
Drilling and Services
Acquisition of Two Jack-Up Platforms	Ps.	553	Ps.	772	Ps.	794	Ps.	834
Acquisition of Nine Land-Based Drilling Rigs		288		340		352		386
Drilling Rig Equipment and Well Service Equipment Maintenance Program		—		74		96		24
Acquisition of Two Modular Drilling Rigs		723		—		3		—
Others		—		1,501		307		190
Total	Ps.	1,564	Ps.	2,688	Ps.	1,550	Ps.	1,434

Notes: Numbers may not total due to rounding.

(1) Amounts based on cash basis method of accounting.

(2) Figures for the drilling and services segment for the year ended December 31, 2015 refer to capital expenditures since August 1, 2015, when Pemex Drilling and Services was formed.

(3) Budget presented to the Board of Directors of Petróleos Mexicanos on March 5, 2018

(4) Figures are stated in nominal pesos.

Source: Petróleos Mexicanos.

Logistics

Our logistics segment operates through the productive state-owned subsidiary Pemex Logistics and provides land, maritime and pipeline transportation, storage and distribution services to some of our other subsidiary entities and to other companies, including CFE, Aeropuertos y Servicios Auxiliares, CENAGAS, local gas stations and distributors.

Transportation of Crude Oil and Refined Products

During 2017, we injected approximately 1,887 thousand barrels per day of crude oil and petroleum products into our pipelines, representing a 10.9% decrease as compared to 2016 when we injected 2,117 thousand barrels per day, mainly due to a reduction in the volume of crude oil processed in the National Refining System and the illicit market in fuels that caused temporary closures of certain pipelines. Of the total amount of crude oil and petroleum products that we transported in 2017, 77.1% was transported by pipeline, 7.8% by tanker and the remaining 15.1% by land transport.

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During 2017, we transported 137.9 thousand barrels per day of LPG, representing a 3.5% decrease as compared to the 142.9 thousand barrels per day transported in 2016. In addition, we transported 2.3 thousand barrels per day of petrochemicals, a decrease of 30.3% as compared to the 3.3 thousand barrels per day we transported in 2016. These decreases were mainly due to a decrease in transportation services requested by Pemex Industrial Transformation, which is the result of importation of LPG by private companies, as well as decreased production of natural gas by Pemex Exploration and Production.

As of 2016, natural gas transportation is carried out by CENAGAS, with the support of Pemex Logistics through an operation and maintenance contract. During 2017, we transported approximately 5,196 million cubic feet per day of natural gas, a 4.5% decrease compared to the 5,440 million cubic feet per day we transported in 2016, mainly due to a decrease in the volume of natural gas requested by the CFE and Pemex Industrial Transformation, as well as decreased production of natural gas by Pemex Exploration and Production.

Treatment and Primary Logistic

We transported an average of 1,431 thousand barrels per day of crude oil in 2017 compared to 1,551 thousand barrels per day in 2016, which represents a decrease of 7.7%, mainly due to lower crude oil production. An average of 756 thousand barrels per day were delivered to the National Refining System and 675 thousand barrels per day were delivered to the export terminals.

During 2017, we transported an average of 3,424 million cubic feet per day of natural gas through the Altamira, Misión, Santuario and Gas Marino Mesozoico transportation systems compared to the 3,765 million cubic feet per day in 2016, which represents a 9.1% decrease, partially due to a decrease in natural gas production by Pemex Exploration and Production. In addition, we transported an average of 26 thousand barrels per day of condensate by the Misión and Condensado Terrestre Sur transportation systems compared to 33 thousand barrels per day in 2016, which represents a 21.2% decrease, partially due to a decrease in natural gas production by Pemex Exploration and Production.

During 2017, we had two leak and spill events, neither of which were significant.

Open Season

As a result of the energy reform, we may now offer pipeline transportation and storage services for refined petroleum products. During 2017, under the guidelines issued by the CRE, Pemex Logistics began participating in “Open Season” auctions, which are auctions intended to be transparent and competitive, wherein any participant can compete to offer its services. Pemex Industrial Transformation has received rights from the CRE to transport up to 59.9 thousand barrels per day and to store up to 1.27 million barrels, a volume sufficient to ensure that national supply is not affected. The remaining capacity will be offered through an Open Season auction conducted by the Aklara, the results of which will be published by the CRE.

On May 2, 2017, we announced the results of the first Open Season auction for the Baja California and Sonora systems. A total of twenty-two companies submitted bids and seven posted bonds. Andeavor (formerly Tesoro Corporation), a U.S. company, was awarded a three-year contract at the assigned capacity at rates above the minimums set by us. We believe that this auction set a foundation for open and free market access to our pipeline and storage infrastructure. We believe such Open Season auctions provide importers and sellers, as well as other actors in the logistical chain, with certainty in the petroleum market.

As a result of the successful first Open Season auction, on July 18, 2017, we executed the contracts with Andeavor, allowing it to use the duct transport and storage system owned by us in the states of Sonora and Baja California. These contracts included access to the Rosarito-Mexicali, Rosarito-Ensenada, Guaymas-Hermosillo and Guaymas-Ciudad Obregón pipelines, as well as the Rosarito, Mexicali and Ensenada storage terminals in Baja California; Guaymas, Ciudad Obregón, Hermosillo, Magdalena, Nogales and Navojoa in Sonora. These contracts provide us with additional resources by maximizing the use of our existing infrastructure capacity.

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Also, in continuation of the Open Season auctions, on December 18, 2017, the CRE approved the auction procedures for the North Border Zone, Pacific Topolobampo Zone and North Zone Madero.

The execution of the Open Season auctions will be carried out sequentially. In March of 2018, we held an auction for the North Border Zone system, which consists of three terminals and two pipeline sections in the states of Coahuila and Tamaulipas. However, since no outside bids were received, the capacity for this sytem will be assigned to Pemex Industrial Information.

We are working with the CRE to review the Open Season auctions procedures in order to attract outside bids in subsequent transactions. We believe that the Open Season auctions provide the basis for fair and competitive bidding for access to our storage and pipeline transportation infrastructure.

Transport and distribution

Our pipelines connect crude oil and natural gas production centers with refineries and petrochemical plants, and our storage terminals with Mexico’s major cities. At the end of 2017, the pipeline network measured approximately 17,397 kilometers in length, of which 17,134 kilometers are currently in operation and 263 kilometers are temporarily out of operation. These pipelines may be temporarily out of operation because of a decline in the production of a field where the pipeline is located or because the transportation service is irregular, which makes its operation unprofitable. Once production is restored in that field, the pipelines become operational again. As of the date of this annual report, we are analyzing the 263 kilometers of pipelines that are temporarily out of operation to determine if and how they may be used in the future.

Approximately 5,216 kilometers of the pipelines currently in operation transport crude oil, 8,390 kilometers of pipelines transport refined petroleum products, 1,395 kilometers of pipelines transport LPG, 2,122 kilometers of pipelines transport basic and secondary petrochemical products, and 274 kilometers transport other products, including fuel oil, jet fuel and water.

We have implemented a pipeline integrity management plan, which requires us to keep detailed documentation on the condition of our pipelines in order to optimize our maintenance investments. The pipeline integrity management plan is based on NOM-027, as well as API RP 1160 for liquid hydrocarbons and ASME B31.8S standards for gas, and includes the following stages:

• collection of detailed records and the development of a pipeline database;

• categorization and identification of threats that could affect pipeline integrity, safety and operation;

• identification of critical points in the pipeline;

• risk assessment, reliability and pipeline integrity;

• maintenance and risk mitigation planning and programming; and

• ongoing monitoring throughout all stages.

We have made considerable progress towards satisfying the requirements of NOM-027 on risk assessment and pipeline integrity. Specifically, as of December 31, 2017, we have analyzed 89% of our overall logistics pipeline network. In addition, we have implemented several measures related to our pipeline integrity management plan, including by collecting information in order to create pipeline databases.

Notwithstanding the implementation of our pipeline integrity management plan, we experienced 32 leaks and spills in 2017. The total number of incidents in 2017 represented a decrease of 8.5% compared to the 35 incidents we experienced in 2016. Of the 32 incidents in our transportation pipelines, 25 were due to a failure in the mechanical integrity of the pipelines, one was due to third-party incidents and six were due to other factors.

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The transportation of crude oil, natural gas and other products through the pipeline network is subject to several risks, including risk of leakage and spills, explosions and theft. In 2017, we spent a total of Ps. 707 million in expenditures for the rehabilitation and maintenance of our pipeline network and we have budgeted an additional Ps. 245 million for these expenditures in 2018. See “Item 3—Key Information—Risk Factors—Risk Factors Related to our Operations—We are an integrated oil and gas company and are exposed to production, equipment and transportation risks, blockades to our facilities and criminal acts and deliberate acts of terror” above.

Fleet Developments

In July of 2013, as part of a plan to modernize the fleet, we signed an agreement with the Secretaría de Marina—Armada de México (Mexican Navy), valued at approximately Ps. 3,212.1 million (U.S.$250.0 million), for the construction of 22 marine vessels for our refining segment. This agreement initially included construction of 16 tugboats, three multipurpose vessels and three barges, but was modified in 2016 to remove the construction of the three barges and to extend the final delivery date to December 31, 2018. This transaction is now valued at approximately Ps. 4,346.4 million. As of December 31, 2017, the Mexican Navy has delivered seven tugboats.

As of December 31, 2017, we owned 16 refined product tankers and leased one. We also own 25 tugboats, 1,485 tank trucks and 511 train tank cars, as well as 76 storage and distribution terminals, ten liquefied gas terminals, five maritime terminals and ten dock operation and maintenance facilities. These facilities, together with our pipeline network, constitute the hydrocarbons transportation and distribution infrastructure.

Our current fleet includes 17 vessels, of which we own 16 and lease one, and altogether we have a transportation capacity of 4,628 thousand barrels. 68% of our vessels are located on the Pacific coast and 32% are in the Gulf of Mexico. Of the capacity of the vessels located on the Pacific coast, 83.4% is used to transport distillates and 16.6% is used to transport fuel oil and heavy diesel. Of the capacity of the vessels located in the Gulf of Mexico, 82.5% is used for distillates and 17.5% is used for fuel oil and heavy diesel.

Our plan for the renewal and modernization of our fleet was concluded in 2014, but we may resume renewal and modernization efforts pursuant to future demand for petroleum products or the retirement of a vessel in accordance with current international regulations.

Logistics Capital Expenditures

Our logistics segment invested Ps. 4,917 million in capital expenditures in 2017 and has budgeted Ps. 4,449 million in capital expenditures for 2018.

The following table sets forth our logistics segment’s capital expenditures, excluding non-capitalizable maintenance, for each of the three years ended December 31, 2015, 2016 and 2017, and the budget for 2018. Capital expenditure amounts are derived from our budgetary records, which are prepared on a cash basis. Accordingly, these capital expenditure amounts do not correspond to capital expenditure amounts included in our consolidated financial statements prepared in accordance with IFRS.

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Logistics’ Capital Expenditures

	Year ended December 31,(1)						Budget 2018(2)
	2015		2016		2017
	(in millions of pesos)(3)
Logistics
Larger Fleet Modernization	Ps.	458	Ps.	583	Ps.	645	Ps.	429
Renewal of Tugs, Chalanes and Multipurpose Vessels of the Smaller Fleet		401		495		258		113
Refurbishment, Modification and Modernization of Pumping and Compression Stations Nationwide		221		476		95		—
Maintenance of Safety, Measurement, Control and Auto-mation Systems in Storage and Distribution Terminals		460		452		235		239
Acquisition of 5 Tankers Vessel by Cash and/or by Leasing		363		427		431		311
Evaluation and Rehabilitation of the Mechanical Integrity of the Pipeline’s Poza Rica-Salamanca and Nuevo Teapa- Tula-Salamanca		461		347		6		—
Replacement of Vessel Tanks Nuevo Pemex I, II, III and IV by Acquisition and/or Leasing		278		326		332		240
Implementation of the SCADA System in 47 Pipeline Transportation Systems		520		270		78		15
Evaluation and Rehabilitation of the Mechanical Integrity of the Pipelines in Northern and Pacific Zones		271		251		316		132
Evaluation and Rehabilitation of the Mechanical Integrity of the Pipelines Nuevo Teapa-Madero-Cadereyta		574		193		88		1
Integral Maintenance of Pipeline Systems for Natural Gas and LPG, Stage II		293		172		205		1
Modernization of the Instrumented Security and Basic Control Systems of the Pumping Stations and Product Receipt Northern Zone		278		110		6		8
Evaluation and Rehabilitation of the Mechanical Integrity of the Turbosine, Diesel, Gasoline and Fuel Oil Pipelines and Gas Pipelines in the Central Zone		464		109		80		204
Natural Gas Transportation from Jáltipan to Salina Cruz Refinery		403		31		12		—
Maintenance of Marine Facilities		316		28		11		—
Others		4,066		2,745		2,120		2,758
Total	Ps.	9,827	Ps.	7,015	Ps.	4,917	Ps.	4,449

Notes: Numbers may not total due to rounding.

(1) Amounts based on cash basis method of accounting.

(2) Budget presented to the Board of Directors of Petróleos Mexicanos on March 5, 2018.

(3) Figures are stated in nominal pesos.

Source: Petróleos Mexicanos.

CENAGAS

Pursuant to the Hydrocarbons Law, on August 11, 2014, CENAGAS was created as a decentralized public entity of the Mexican Government to act as the independent administrator of the Integrated Natural Gas System. This system interconnects the infrastructure for the storage and transportation of natural gas across the nation, with the aim of expanding coverage, strengthening security measures and improving the continuity, quality and

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efficiency in transportation service. As an integrated system of transportation systems owned by CENAGAS or other participating companies, the Integrated Natural Gas System functions as a primary transportation service supplier in Mexico with standardized fares. Within this system, the Sistema Nacional de Gasoductos (National Gas Pipelines System) acts as the commercial administrator for the total available capacity of the Integrated Natural Gas System. In order for a transportation system to become part of the Integrated Natural Gas System, its transport capacity must enhance the Integrated Natural Gas System’s flow capacity and improve the overall transportation service provided to users.

In accordance with the Energy Reform Decree, we signed a transfer agreement with CENAGAS on October 29, 2015 for the transfer to CENAGAS of assets associated with the Integrated Natural Gas System and the distribution contract for the Naco-Hermosillo pipeline system. The National Gas Pipeline System has 87 pipelines with a total length of almost 9,000 kilometers and a transport capacity over 5,000 million cubic feet per day, while the Naco-Hermosillo system is a 300 kilometers long pipeline with a transport capacity of 90 million cubic feet per day. The approximate aggregate book value of these assets, which were transferred to CENAGAS on January 1, 2016, was Ps. 35.3 billion as of December 31, 2016.

On December 29, 2016, we entered into two agreements with CENAGAS pursuant to which we continued to provide operation and maintenance services and commercial operation services to CENAGAS during 2017. Both agreements, which have a total value of approximately Ps. 249 billion and Ps. 13 billion, respectively, were one-year agreements with automatic renewals unless either party gives advance notice to the contrary. As of the date of this annual report, CENAGAS has given us notice of termination for nine of the 21 pipeline subsystems.

During 2017 we obtained Ps. 3,268.2 million from our services provided to CENAGAS.

Cogeneration and Services

For the past three years, our cogeneration and services segment has operated through the productive state-owned subsidiary Pemex Cogeneration and Services to use thermal heat and steam from our industrial processes to produce the electricity required by us, as well as surplus electricity to sell to third parties in Mexico. Our cogeneration and services segment has also provided technical and management services associated with supplying electricity.

Partly in response to prolonged periods of low hydrocarbon prices, and as part of our broader strategy to enter into strategic alliances, we have transferred certain assets and functions of Pemex Cogeneration and Services to Pemex Industrial Transformation. The primary goal of these transfers is to focus our efforts on our core activities and to enter into alliances for the operation and maintenance of our cogeneration plants and the commercialization of surplus energy. We believe that this focus on core activities and strategic alliances will allow us to reduce unscheduled stoppages, improving reliability throughout our supply chain and reducing costs, which we expect will improve Pemex Industrial Transformation’s financial results. We estimate that, as a result of these transfers to Pemex Industrial Transformation, we will be able to achieve significant cost savings of U.S. $103 million. Moreover, we expect that the development of cogeneration projects in cooperation with our allies in our Tula and Cadereyta refineries will result in additional cost savings of U.S. $466 million.

During 2017, Pemex Cogeneration and Services generated Ps. 334.8 million in services income and had a net loss of Ps. 92.1 million.

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International Trading

PMI and its subsidiaries conduct international commercial activities for our crude oil, refined and petrochemical products, with the exception of natural gas, which is marketed directly by our industrial transformation segment. The PMI subsidiaries’ main objectives are to assist in maximizing our profitability and optimizing our operations through the use of international trade, facilitating our link with the international markets and pursuing new business opportunities in marketing our products. PMI and its subsidiaries manage the international sales of our crude oil and petroleum products and acquire in the international markets those petroleum products that we import to satisfy domestic demand. Sales of crude oil are carried out through PMI. Sales and purchases of petroleum products in the international markets are carried out through P.M.I. Trading, Ltd., which also performs third-party trading, transportation and risk management activities.

Exports and Imports

PMI purchases crude oil from our exploration and production segment and then sells it to PMI’s customers. PMI sold an average of 1,174.0 thousand barrels of crude oil per day in 2017, which represented 60.3% of our total crude oil production.

The following tables set forth the composition and average prices of our crude oil exports for the periods indicated.

	Year ended December 31,
	2013				2014				2015				2016				2017
	(tbpd)		(%)		(tbpd)		(%)		(tbpd)		(%)		(tbpd)		(%)		(tbpd)		(%)
Crude Oil Exports (by Volume)
Olmeca (API gravity of 38°-39°)		99		8		91		8		124		11		108		9		19		2
Isthmus (API gravity of 32°-33°)		103		9		134		12		194		17		153		13		86		7
Maya (API gravity of 21°-22°)		968		81		887		78		743		63		865		72		1,054		90
Altamira (API gravity of 15.0°-16.5°)		20		2		27		2		28		2		24		2		15		1
Talam (API gravity of -15.8º)		—		—		3		0.3		83		7		45		4		—		—
Total		1,189		100		1,142		100		1,172		100		1,194		100		1,174		100

Notes: Numbers may not total due to rounding.

tbpd = thousand barrels per day.

API gravity refers to the specific gravity or density of liquid petroleum products, measured in degrees on the American Petroleum Institute (API) scale. On the API scale, oil with the lowest specific gravity has the highest API gravity. In addition, holding all other factors constant, the higher the API gravity, the greater the value of the crude oil.

Source: PMI operating statistics as of January 9, 2018.

	Year ended December 31,
	2013		2014		2015		2016		2017
	(U.S. dollars per barrel)
Crude Oil Prices
Olmeca	U.S.$	107.92	U.S.$	93.54	U.S.$	51.46	U.S.$	39.71	U.S.$	51.79
Isthmus		104.69		93.39		49.28		37.72		50.75
Maya		96.89		83.75		41.12		35.30		46.41
Altamira		94.35		81.30		36.19		30.35		39.45
Talam		—		36.74		36.40		28.44		—
Weighted average realized price	U.S. $	98.44	U.S. $	85.48	U.S. $	43.12	U.S. $	35.65	U.S. $	46.73

Source: PMI operating statistics as of January 9, 2018.

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Geographic Distribution of Export Sales

As of December 31, 2017, PMI had more than 30 customers in 12 countries. Since 2013, the proportion of our crude oil export sales to the United States has declined, while the proportion of our crude oil export sales to Europe and Asia has increased. In 2017, 53% of our crude oil export sales were to customers in the United States, which represents a 21% decrease as compared to 2013. Since 2013, primarily as a result of increased availability of light crude oil in the United States and other developing trends in international demand for imported crude oil, we have expanded the scope of our geographic distribution and adapted our strategy to diversify and strengthen the position of Mexican crude oil in the international market. As part of that strategy, in January 2014, PMI started exporting Olmeca crude oil to several European countries and in recent years PMI has expanded its export sales in Asia and continued to do so in 2017.

The following table sets forth the geographic distribution of PMI’s sales of crude oil exports for the five years ended December 31, 2017. The table also presents the distribution of exports among PMI’s crude oil types for those years:

Composition and Geographic Distribution of Crude Oil Export Sales

	Year ended December 31,
	2013				2014				2015				2016				2017
	(tbpd)		(%)		(tbpd)		(%)		(tbpd)		(%)		(tbpd)		(%)		(tbpd)		(%)
PMI Crude Oil Export Sales to:
United States and Canada		879		74		813		71		690		59		572		48		617		53
Europe		179		15		215		18		248		21		273		23		219		19
Asia		116		10		100		9		219		19		319		27		317		27
Central and South America		15		1		15		1		15		1		34		3		20		2
Total		1,189		100		1,142		100		1,172		100		1,198		100		1,174		100
Olmeca (API gravity of 38°-39°)
United States and Canada		90		8		35		3		40		4		4		0.3		—		—
Others		8		1		56		5		84		7		104		9		19		2
Total		99		8		91		8		124		11		108		9		19		2
Isthmus (API gravity of 32°-33°)
United States and Canada		62		5		89		8		78		7		3		0.3		5		0.4
Others		41		3		45		4		116		10		150		13		81		7
Total		103		9		134		12		194		17		153		13		86		7
Maya (API gravity of 21°-22°)
United States and Canada		707		60		662		58		513		44		541		45		597		51
Others		260		22		225		20		230		20		326		27		457		39
Total		968		81		887		78		743		63		867		72		1,054		90
Altamira (API gravity of 15.0°-16.5°)
United States and Canada		20		2		27		2		28		2		22		2		15		1
Others		—		—		0.4		0.04		—		—		2		0.2		—		—
Total		20		2		27		2		28		2		24		2		15		1
Talam (API gravity of 15.8º)
United States and Canada		—		—		—		—		31		3		1		0.1		—		—
Others		—		—		3		0.3		52		4		44		4		—		—
Total		—		—		3		0.3		83		7		45		4		—		—

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Notes: Numbers may not total due to rounding.

tbpd = thousand barrels per day.

API gravity refers to the specific gravity or density of liquid petroleum products, measured in degrees on the API scale. On the API scale, oil with the lowest specific gravity has the highest API gravity. In addition, holding all other factors constant, the higher the API gravity, the greater the value of the crude oil.

Source: PMI operating statistics as of April 2018.

In total, we exported 1,174.0 thousand barrels of crude oil per day in 2017, and in 2018 we expect to export approximately 1,100.0 thousand barrels of crude oil per day. We sell the crude oil produced by Pemex Exploration and Production under a variety of contractual arrangements. Of the 1,100.0 thousand barrels of crude oil per day we expect to export in 2018, we are contractually committed to deliver approximately 980.0 thousand barrels per day pursuant to existing supply commitments. We believe that our proved developed and proved undeveloped reserves will be sufficient to allow us to fulfill our supply commitments.

The following table sets forth the average volume of our exports and imports of crude oil, natural gas and petroleum products for the five years ended December 31, 2017.

Volume of Exports and Imports

	Year ended December 31,										2017 vs. 2016
	2013		2014		2015		2016		2017
	(in thousands of barrels per day, except as noted)										(%)
Exports
Crude Oil:
Olmeca		98.6		91.2		124.2		108.0		18.9		(82.5	)
Isthmus		102.7		133.7		194.0		152.7		85.8		(43.8	)
Maya		967.6		887.1		743.4		864.9		1,054.0		21.9
Altamira		19.9		27.2		27.8		23.6		15.3		(35.2	)
Talam		—		3.0		83.1		45.2		—		(100	)
Total crude oil		1,188.8		1,142.2		1,172.4		1,194.3		1,174.0		(1.7	)
Natural gas(1)		3.1		4.1		2.7		2.2		1.7		(22.7	)
Gasoline		66.8		66.0		62.9		52.7		45.0		(14.6	)
Other petroleum products		109.6		133.3		130.8		132.9		113.1		(14.9	)
Petrochemical products(2)(3)		614.3		406.1		333.8		124.7		60.4		(51.6	)
Imports
Natural gas(1)		1,289.7		1,357.8		1,415.8		1,933.9		1,766.0		(8.7	)
Gasoline		375.2		389.7		440.1		510.8		582.5		14.0
Other petroleum products and LPG(1)(4)		226.3		248.7		299.7		289.6		353.6		22.1
Petrochemical products(2)(5)		74.1		85.3		107.3		278.2		332.8		19.6

Note: Numbers subject to adjustment because crude oil exports may be adjusted to reflect the percentage of water in each shipment.

(1) Numbers expressed in millions of cubic feet per day.

(2) Thousands of metric tons.

(3) Includes propylene.

(4) In 2013, we began importing liquefied natural gas through Manzanillo.

(5) Includes isobutane, butane and N-butane.

Source: PMI operating statistics as of January 9, 2018, and Pemex Industrial Transformation.

Crude oil exports decreased by 1.7% in 2017, from 1,194.3 thousand barrels per day in 2016 to 1,174.0 thousand barrels per day in 2017, mainly due to an increase of exports of 21.9% of Maya crude oil, which was partially offset by a 43.8% decrease in exports of Isthmus crude oil and a decrease of 82.5% in Olmeca crude oil export during 2017.

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Natural gas imports decreased by 8.7% in 2017, from 1,933.9 million cubic feet per day in 2016 to 1,766.0 million cubic feet per day in 2017, which includes imports of liquefied natural gas through Manzanillo. This decrease is primarily due to a decrease in the volume of sales required by the electricity sector.

In 2017, exports of petroleum products decreased by 14.8%, from 185.5 thousand barrels per day in 2016 to 158.0 thousand barrels per day in 2017, mainly due to a 74.2% decrease in the volume of exports of diluent, an 8.6% decrease in the volume of sales of oil fuel and a 14.6% decrease in the volume of sales of natural gasoline. Imports of petroleum products increased by 17.0% in 2017, from 800.4 thousand barrels per day in 2016 to 936.2 thousand barrels per day in 2017, primarily due to a decrease in domestic production of petroleum products.

P.M.I. Trading, Ltd. sells refined and petrochemical products on an FOB, Delivered Ex-ship and Cost and Freight basis and buys refined and petrochemical products on an FOB, Cost and Freight and Delivered Ex-ship or Delivery at Frontier basis.

The following table sets forth the value of exports and imports of crude oil, natural gas and petroleum products for the five years ended December 31, 2017.

Value of Exports and Imports⁽¹⁾

	Year ended December 31,												2017 vs. 2016
	2013		2014		2015		2016			2017
	(in millions of U.S. dollars)												(%)
Exports
Olmeca	U.S.$	3,883.9	U.S.$	3,114.7	U.S.$	2,333.1	U.S.$	1,569.4		U.S.$	358.1			(77.2	)
Isthmus		3,925.7		4,557.1		3,489.0		2,107.6			1,589.1			(24.6	)
Altamira		683.7		806.8		366.6		262.4			219.8			(16.2	)
Maya		34,217.9		27,119.4		11,158.8		11,172.7			17,856.4			60.0
Talam		—		40.4		1,103.6		470.1			—			(100	)
Total crude oil(2)	U.S.$	42,711.2	U.S.$	35,638.4	U.S.$	18,451.1	U.S.$	15,582.2		U.S$	20,023.4			28.5
Natural gas		2.8		4.8		1.6		1.1			1.3			18.2
Gasoline		2,162.5		1,985.9		1,007.4		733.2			746.9			1.9
Other petroleum products		3,364.6		3,425.7		1,580.2		1,161.9			1,655.6			42.5
Petrochemical products		171.0		132.4		63.5		20.5			37.7			84.0
Total natural gas, petroleum and petrochemical products	U.S.$	5,700.8	U.S.$	5,548.8	U.S.$	2,652.7	U.S.$	1,916.7		U.S.$	2,441.4			27.4
Total exports	U.S.$	48,412.0	U.S.$	41,187.2	U.S.$	21,103.8	U.S.$	17,498.9		U.S.$	22,464.8			28.4
Imports
Natural gas	U.S.$	2,495.3	U.S.$	2,819.3	U.S.$	1,673.7	U.S.$	2,097.9		U.S.$	2,484.1			18.4
Gasoline		17,485.9		16,691.2		12,805.2		11,994.8			15,380.1			28.2
Other petroleum products and LPG		8,153.9		8,738.7		6,178.6		5,699.9			8,446.3			48.2
Petrochemical products		128.9		168.1		196.3		85.5			122.5			43.3
Total imports	U.S.$	28,264.0	U.S.$	28,417.3	U.S.$	20,853.7	U.S.$	19,878.1		U.S.$	26,433.0			33.0
Net exports (imports)	U.S.$	20,148.0	U.S.$	12,769.9	U.S.$	250.1	U.S.$	(2,379.2	)	U.S.$	(3,968.2	)		66.8

Note: Numbers may not total due to rounding.

(1) Does not include crude oil, refined products and petrochemicals purchased by P.M.I. Trading, Ltd. or PMI-NASA from third parties outside of Mexico and resold in the international markets. The figures expressed in this table differ from the amounts contained under the line item “Net Sales” in our financial statements because of differences in methodology associated with the calculation of the exchange rates and other minor adjustments.

(2) Crude oil exports are subject to adjustment to reflect the percentage of water in each shipment.

Source: PMI operating statistics as of January 9, 2018, which are based on information in bills of lading, and Pemex Industrial Transformation.

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Imports of natural gas increased in value by 18.4% during 2017, primarily as a result of an increase in the average sales price of natural gas. Imports of gasoline increased in value by 28.2% due to an increase in volume of domestic gasoline sales and in the average sales price of gasoline.

The following table describes the composition of our exports and imports of selected refined products in 2015, 2016 and 2017.

Exports and Imports of Selected Petroleum Products

	Year ended December 31,
	2015					2016					2017
	(tbpd)		(%)			(tbpd)		(%)			(tbpd)		(%)
Exports
Liquefied petroleum gas(1)		—		—			4.5		2.4			5.7		3.6
Fuel oil		123.9		64.0			113.3		61.0			103.5		65.5
Gasoline		62.9		32.5			52.7		28.4			45.0		28.4
Others		6.8		3.5			15.1		8.2			3.9		2.5
Total		193.7		100.0	%		185.5		100.0	%		158.0		100.0	%
Imports
Gasoline(3)		440.1		59.5			510.8		63.8			582.5		62.2
Fuel oil		17.0		2.3			10.7		1.3			24.4		2.6
Liquefied petroleum gas(2)		105.2		14.2			50.6		6.3			42.6		4.5
Diesel		145.3		19.6			187.8		23.5			237.5		25.4
Others		32.2		4.3			40.4		5.1			49.1		5.2
Total		739.8		100.0	%		800.4		100.0	%		936.2		100.0	%

Notes: Numbers may not total due to rounding.

          tbpd = thousand barrels per day.

(1) Includes butanes and propane.

(2) Includes methyl tert-butyl ether (MTBE).

(3) Includes premium gasoline, regular gasoline, premium components and naphtas

Source: Pemex BDI.

Exports of petroleum products increased in value by 26.8% in 2017, primarily due to a 59.9% increase in sales of fuel oil and increases in the prices of petroleum products. In 2017, imports of petroleum products increased in value, by 34.7%, primarily due to a 17.0% increase in volume of imports due to increased domestic demand for regular gasoline and an increase in the average price of gasoline as compared to prior year. Our net imports of petroleum products for 2017 totaled U.S. $21,423.9 million, which represents a 35.6% increase from our net imports of petroleum products of U.S. $15,799.0 million in 2016.

The Secretary of Energy has entered into certain agreements to reduce or increase crude oil exports. See “Item 4—Information on the Company—Trade Regulation and Export Agreements” below in this Item 4.

Hedging Operations

P.M.I. Trading, Ltd. engages in hedging operations to cover its price exposure in the trading of petroleum products. The internal policies and procedures of P.M.I. Trading, Ltd. establish: (1) that DFIs are used exclusively to mitigate the volatility of oil and gas prices; (2) limits on the maximum amount of capital at risk and on the daily and accumulated annual losses for each business unit; and (3) the segregation of risk-taking and risk measurement. Capital at risk is calculated on a daily basis in order to compare the actual figures with the aforementioned limit. P.M.I. Trading, Ltd. has a risk management subcommittee that reviews risk and hedging

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operations and meets on a quarterly basis. See “Item 11—Quantitative and Qualitative Disclosures about Market Risk—Changes in Exposure to Main Risks—Hydrocarbon Price Risk.”

Gas Stations in the United States

Between late 2015 and early 2016, we opened five gas stations in Houston, Texas that are owned and operated by franchisees. This is part of our strategy to expand our operations to the United States in order to fulfill the energy reform mandate to generate economic value in international markets. Further, it will allow us to measure the impact of our brand against others and identify business opportunities abroad. The gas stations’ fuel supply is derived from the United States wholesale market and selling prices are subject to local market conditions. As of December 31, 2017, we have seen an increase in fuel consumption of up to 150% as compared to 2016, primarily in areas with large Hispanic populations. We are looking to build on this strategy and expand our presence in the United States over the next several years.

PEMEX Corporate Matters

In addition to the operating activities that we undertake through the activities of our subsidiary entities and subsidiary companies, we have certain centralized corporate operations that coordinate general labor, safety, insurance and legal matters.

Industrial Safety and Environmental Protection

Our Corporate Office of Planning, Coordination and Performance is responsible for planning, conducting and coordinating programs to:

• foster a company culture of safety and environmental protection;

• improve the safety of our workers and facilities;

• reduce risks to residents of the areas surrounding our facilities; and

• reduce greenhouse gas emissions and identify the risks associated with climate change in Mexico in order to develop strategies to minimize the impact of climate change on our operations.

We intend to further develop industrial safety and environmental programs for each subsidiary entity. The environmental and safety division of each subsidiary entity coordinates closely with the Corporate Office of Planning, Coordination and Performance.

Insurance

We maintain a comprehensive property and general liability insurance program for onshore and offshore properties and liabilities. All onshore properties, such as refineries, processing plants, pipelines and storage facilities are covered, as are all of our offshore assets, such as drilling platforms, rigs, gas gathering systems, maritime terminals and production facilities.

Our insurance covers risks of sudden and accidental physical damage to or destruction of our properties, as well as risk of sudden and accidental physical loss, including as a consequence of purposeful terrorist acts. This insurance also provides coverage for the contents of pipelines and storage facilities, and any of our liabilities arising from such acts. Our insurance also covers extraordinary costs related to the operation of offshore wells, such as control and re-drilling costs, evacuation expenses and liability costs associated with spills. We also maintain protection and indemnity insurance for our full marine fleet, in addition to life insurance, automobile and heavy equipment insurance, cargo and marine hull insurance, as well as insurance for deep water drilling activities and onshore and offshore construction on operating facilities.

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In accordance with Mexican law, we have entered into all of our insurance contracts with Mexican insurance carriers. These policies have limits of U.S. $1.8 billion for onshore property, U.S. $1.9 billion for offshore property, U.S. $0.3 billion for extraordinary costs related to the operation of offshore wells, U.S. $1.0 billion for marine-related liabilities, U.S. $1.1 billion for onshore and offshore liabilities, U.S. $0.5 billion for offshore terrorist acts and U.S. $0.5 billion for onshore terrorist acts. Limits of insurance policies purchased for each category of risk are determined using professional risk management assessment surveys conducted by international companies on an annual basis and the market capacity available per risk, and must be in compliance with local regulations enacted following the energy reform. In addition, in compliance with the regulations enacted in June of 2016 by the National Agency for Industrial Safety and Environmental Protection of the Hydrocarbons Sector (ASEA), we maintain insurance coverage with respect to third party liability, liability for environmental damage and control of well, works or drilling activities and extraction of hydrocarbons, the treatment and refining of crude oil and the processing of natural gas. We have also made the necessary endorsements to ensure that we maintain insurance coverage in connection with our new strategic alliances and other joint arrangements.

Since June 2003, we have not maintained business interruption insurance, which in the past compensated us for loss of revenues resulting from damages to our facilities. Instead, we purchase ad-hoc business interruption mitigation insurance coverage, which compensates us for the additional expenses necessary to recover our production capabilities in the shortest time possible.

During 2017 we continued to engage in deep water exploratory and drilling activities that were covered by our existing insurance program. In August 2012, we purchased a policy to increase the coverage available for potential property damage, third-party liability and control of well risks related to these activities. Under this policy, we maintain coverage for each deep water well drilled, and the limits are determined based on the risk profile of the corresponding well. This policy has a limit of U.S. $3.3 billion, including U.S. $1.3 billion for control of well risks, U.S. $1.1 billion for casualty and U.S. $0.9 billion for property damage. This policy also contemplates additional coverage for environmental liabilities and remediation activities relating to deep water exploration and drilling.

All of our insurance policies are in turn reinsured through Kot Insurance Company, AG (which we refer to as Kot AG). Kot AG is a wholly owned subsidiary company that was originally formed in 1993 under the laws of Bermuda as Kot Insurance Company, Ltd. and was subsequently organized under the laws of Switzerland in 2004. Kot AG is used as a risk management tool to structure and distribute risks across the international reinsurance markets. The purpose of Kot AG is to reinsure policies held through our local insurance carriers and to maintain control over the cost and quality of the insurance covering our risks. Kot AG reinsures over 90% of its reinsurance policies with unaffiliated third-party reinsurers. Kot AG carefully monitors the financial performance of its reinsurers and actively manages counterparty credit risk across its reinsurance portfolio to ensure its own financial stability and maintain its creditworthiness. Kot AG maintains solid capitalization and solvency margins consistent with guidelines provided by Swiss insurance authorities and regulations. As of December 31, 2017, Kot AG’s net risk retention is capped at U.S. $327 million spread across different reinsurance coverages to mitigate potential aggregation factors.

Investment in Repsol

On October 26, 2017, PMI HBV sold all of its shares in Repsol, S.A. (formerly known as Repsol YPF, S.A., and which we refer to as Repsol)—21,333,870 shares in total – to Credit Agricole CIB. This sale resulted in a loss of Ps. 3.5 billion. As of the date of this annual report, we do not hold any shares in Repsol. See Note 10 to our consolidated financial statements included herein.

Ethics Committee

Our Ethics Committee consists of members from our management team, with the head of the Institutional Internal Control Unit at Petróleos Mexicanos serving as its chairman.

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Our Ethics Committee is primarily responsible for:

• promoting awareness and use of our code of ethics and code of conduct, including through online training available for our employees, in order to improve our culture of ethics;

• establishing procedures that implement the principles found in our code of ethics in order to increase compliance and to detect behavior that adversely affects our activities;

• analyzing and giving instructions to the appropriate areas on possible violations to our code of ethics and code of conduct that are reported through the Ethics Line; and

• working with the Liabilities Unit at Petróleos Mexicanos and our Internal Auditing Area to exchange information regarding violations of our code of ethics and our code of conduct.

See “Item 16B—Code of Ethics” for more information regarding our code of ethics.

Collaboration and Other Agreements

On September 30, 2014, Petróleos Mexicanos and the Secretaria de Desarrollo Social (SEDESOL), signed a collaboration agreement with the objective of supporting community development in the zones of influence of oil industries by providing food and nutrition support as part of the Cruzada Nacional Contra el Hambre (National Cruzade Against Hunger). This collaboration agreement expired in November 2017.

On October 27, 2014, Petróleos Mexicanos and the Secretaria de Agricultura, Ganadería, Desarrollo Rural, Pesca y Alimentación (SAGARPA) signed a collaboration agreement to provide community and environmental support to communities within the zones of influence of the oil industries. This collaboration agreement is set to expire in November 2018.

On February 5, 2015, Petróleos Mexicanos and the Instituto Politécnico Nacional (National Polytechnic Institute) of Mexico entered into a collaboration agreement for the development of human resources, technology and research, with the aim of promoting and supporting joint research programs and the development of knowledge related to the hydrocarbons industry.

On February 18, 2015, Petróleos Mexicanos and the Organisation for Economic Co-operation and Development (OECD) signed a memorandum of understanding with the aim of benefiting from the OECD’s knowledge of and experiences with international best practices relating to the procurement of goods and services.

On February 19, 2015, Petróleos Mexicanos signed a memorandum of understanding with the Infraestructura Energética Nova, S.A.B. de C.V. and Sempra LNG units of the U.S. energy company Sempra Energy for the potential joint development of a natural gas liquefaction project at the site of the Energía Costa Azul facility located in Ensenada, Mexico.

On April 7, 2015, Petróleos Mexicanos and First Reserve signed a memorandum of understanding and cooperation to explore new opportunities for joint energy projects, which would provide access to financing, as well as the exchange of technical and operational experience. This agreement contemplates up to U.S. $1.0 billion of investments in potential projects relating to infrastructure, maritime transport and power cogeneration, among others.

On May 12, 2015, Petróleos Mexicanos and Global Water Development Partners, a company founded by private equity funds operated by Blackstone, signed a memorandum of understanding with the aim of creating a partnership to invest in water and wastewater infrastructure for Petróleos Mexicanos’ upstream and downstream facilities. This partnership is intended to finance and carry out environmentally sustainable projects for water treatment in Petróleos Mexicanos’ operations.

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On May 12, 2015, PMX Cogeneración, S.A.P.I. de C.V., an affiliate of Petróleos Mexicanos, signed a memorandum of understanding with the consortium formed by Enel S.p.A., an Italian renewable energy company, and Abengoa, S.A., a Spanish renewable energy company, to develop a cogeneration power plant to generate and supply clean energy to the Antonio Dovali Jaime refinery in Salina Cruz, as well as the Mexican national grid.

On June 1, 2015, Petróleos Mexicanos and the U.S. based global asset manager BlackRock Inc. signed a memorandum of understanding with the aim of accelerating the development and financing of energy-related infrastructure projects that are of strategic importance to Petróleos Mexicanos.

On July 20, 2015, Petróleos Mexicanos, through its Corporate Office of Procurement and Supply, signed an agreement with the OECD with the aim of adopting and promoting best practices in procurement and fostering efficient management strategies and transparency in Petróleos Mexicanos’ processes. The agreement also contemplates the training of our personnel by the OECD on issues of transparency and ethics, the design of procurement procedures and mitigating risks of collusion.

On July 22, 2015, Petróleos Mexicanos and the Secretaría de Desarrollo Agrario, Territorial y Urbano (Ministry of Agriculture, Land and Urban Development) signed a collaboration agreement with the aim of establishing consulting and training mechanisms for the development of hydrocarbon exploration, extraction and distribution projects in strict observance of the applicable legal framework and with full respect for agricultural landowners.

On July 23, 2015, Petróleos Mexicanos and the Instituto Tecnológico y de Estudios Superiores de Monterrey, A.C. signed a collaboration agreement with the purpose of (1) fostering competitive development within the Mexican oil and gas industry; (2) carrying out specialized research and consulting services, including lectures, seminars, conferences and other events of common interest to the institutions; and (3) providing postgraduate studies for our employees and internships for college students at Petróleos Mexicanos.

On July 28, 2015, Petróleos Mexicanos and Banco Santander, S.A. (Santander) signed a collaboration agreement with the purpose of providing our franchisees with access to Santander banking services such as bank card sales, deposits and e-banking services, payroll management and the transportation of money.

On September 9, 2015, Petróleos Mexicanos and General Electric signed a memorandum of understanding with the aim of creating a partnership to invest in new technology and financing initiatives for gas compression, power generation and the production of hydrocarbons, both onshore and offshore, including in deepwater fields.

On October 7, 2015, Petróleos Mexicanos, through its subsidiary Pemex Cogeneration and Services, and Dominion Technologies signed a memorandum of understanding to form a company aimed at the joint implementation of cogeneration projects.

On October 10, 2015, Petróleos Mexicanos and the United Nations Development Programme in Mexico reaffirmed their commitment to use best practices in terms of inclusion, equality and non-discrimination in the workplace.

On November 30, 2015, Petróleos Mexicanos and Global Water Development Partners agreed to create a joint venture intended to invest approximately U.S. $800 million in water and wastewater treatment infrastructure for upstream and downstream facilities in Mexico. This partnership aims to (1) provide access to advanced technology to meet the supply and treatment requirements of wastewater at our facilities, in both onshore and offshore production areas, as well as in refineries and petrochemical plants; and (2) in the future, to potentially implement and finance environmentally sustainable solutions for water management.

On January 19, 2016, Petróleos Mexicanos and Mubadala Petroleum signed a memorandum of understating agreeing to joint projects to explore the Mexican energy sector, including its upstream activities, primary

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midstream activities and infrastructure projects for a total investment of approximately U.S. $4.0 billion. Among these projects is a commercial logistic infrastructure system in the Salina Cruz, Oaxaca area, for an approximate investment in excess of U.S. $3.0 billion.

On January 19, 2016, Petróleos Mexicanos and the Abu Dhabi National Oil Company signed a memorandum of understanding with the aim to share each company’s best practices with respect to different upstream activities, including exploration, development and production in oil fields; improved recovery, handling and processing of liquefied natural gas; as well as human resources training, sustainability, internal controls, transparency, process development and cyber-security.

On January 19, 2016, Petróleos Mexicanos and Saudi Aramco signed a memorandum of understanding renewing and strengthening the relationship between both companies and establishing an exchange of ideas surrounding operational excellence, sustainability and energy efficiency, and innovation and technological development.

These broad agreements of technological and scientific collaboration are strictly non-commercial, i.e., there is no transfer of resources among the parties.

Property, Plants and Equipment

General

Substantially all of our property, consisting of refineries, storage, production, manufacturing and transportation facilities and certain retail outlets, is located in Mexico, including Mexican waters in the Gulf of Mexico. The location, character, utilization and productive capacity of our exploration, drilling, refining, petrochemical production, transportation and storage facilities are described above. See “—Exploration and Production,” “—Drilling and Services,” “Industrial Transformation,” “—Ethylene,” “—Fertilizers,” “—Logistics” and “—Cogeneration and Services.” The insurance program covering all of our properties is also described above. See “—Insurance.”

Reserves

Under Mexican law, all crude oil and other oil and gas reserves located in the subsoil of Mexico are owned by the Mexican nation and not by us. The Mexican Government has granted us the right to exploit the petroleum and other oil and gas reserves assigned to us in connection with Round Zero, as well as the right to explore for and exploit petroleum and other oil and gas reserves in areas that have been granted to us in Round 1.4. Productive state-owned companies and other companies participating in the Mexican oil and gas industry may report assignments or contracts and the corresponding expected benefits for accounting and financial purposes. See “Information on the Company—History and Development—Energy Reform” above in this Item 4. Our estimates of hydrocarbons reserves are described under “—Exploration and Production—Reserves” above.

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GENERAL REGULATORY FRAMEWORK

Petróleos Mexicanos is regulated by the Mexican Constitution, the Petróleos Mexicanos Law and the Hydrocarbons Law, among other regulations. The purpose of the Petróleos Mexicanos Law is to regulate the organization, management, operation, monitoring, evaluation and accountability of Petróleos Mexicanos as a productive-state owned company of the Mexican Government. On October 31, 2014, the Regulations to the Petróleos Mexicanos Law were published in the Official Gazette of the Federation. These regulations were modified on February 9, 2015. The purpose of these regulations is to regulate, among other things, the appointment and removal of the members of the Board of Directors of Petróleos Mexicanos, potential conflicts of interest for Board members, and the evaluation of Petróleos Mexicanos.

The Mexican Government and its ministries regulate our operations in the oil and gas sector. The Ministry of Energy monitors our operations, and the Secretary of Energy acts as the chairperson of the Board of Directors of Petróleos Mexicanos. In addition, the Ley de los Órganos Reguladores Coordinados en Materia Energética (Coordinated Energy Regulatory Bodies Law related to the Energy Matters Law, which was enacted as part of the Secondary Legislation and took effect on August 12, 2014) establishes mechanisms for the coordination of these entities with the Ministry of Energy and other ministries of the Mexican Government. The CNH has the authority to award and execute contracts for exploration and production in connection with competitive bidding rounds. The CRE has the authority to grant permits for the storage, transportation and distribution of oil, gas, petroleum products and petrochemicals in Mexico, and to regulate the first-hand sale of these products. The regulatory powers of the CNH and the CRE extend to all oil and gas companies operating in Mexico, including Petróleos Mexicanos and our subsidiary entities.

On December 2, 2014, the Ministry of Energy published in the Official Gazette of the Federation a statement declaring that the new Board of Directors of Petróleos Mexicanos was performing its duties and the mechanisms for our oversight, transparency and accountability had been implemented in accordance with the Petróleos Mexicanos Law. As a result, the special regime that governs Petróleos Mexicanos’ activities relating to productive state-owned subsidiaries, affiliates, compensation, assets, administrative liabilities, budget, debt levels and the state dividend took effect. On June 10, 2015 the General Provisions for Contracting with Petróleos Mexicanos and its Productive State-Owned Subsidiaries were published in the Official Gazette of the Federation, and on June 11, 2015, the special regime for acquisitions, leases, services and public became effective. In accordance with the Petróleos Mexicanos Law, each year the Ministry of Finance and Public Credit provides us with estimated macroeconomic indicators for the following fiscal year, which we are to use to prepare the consolidated annual budget for Petróleos Mexicanos and the subsidiary entities, including our financing program. Upon approval by the Board of Directors of Petróleos Mexicanos, our consolidated budget and financing program is then submitted to the Ministry of Finance and Public Credit, which has the authority to adjust our financial balance goal and the ceiling on our wage and salary expenditures for the fiscal year. The consolidated annual budget and financing program of Petróleos Mexicanos and the subsidiary entities, including any adjustments made by the Ministry of Finance and Public Credit, is then incorporated into the federal budget for approval by the Chamber of Deputies. The Mexican Government is not, however, liable for the financial obligations that we incur. In approving the federal budget, the Chamber of Deputies authorizes our financial balance goal and the ceiling on our wage and salary expenditures for the fiscal year, which it may subsequently adjust at any time by modifying the applicable law.

We are also subject to various domestic and international laws and regulations related to anti-corruption, anti-bribery and anti-money laundering. The Código Penal Federal (Federal Criminal Code) criminalizes certain corrupt practices, including bribery, embezzlement and abuse of authority. The Ley Federal Anticorrupción en Contrataciones Públicas (Federal Law of Anti-Corruption in Public Contracting) sanctions companies and individuals that violate this law while participating in federal government contracting in Mexico, as well as Mexican companies and individuals engaged in international commercial transactions. This law is analogous in many respects to the FCPA. In addition, the Federal Law of Administrative Responsibilities of Public Officials prohibits the bribery of federal public officials in Mexico, including members of the Mexican Congress and the federal judiciary.

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We also employ internal control procedures and guidelines designed to monitor the activities of our employees, including senior management, and to ensure compliance with applicable anti-corruption, anti-bribery and anti-money laundering laws and regulations. The Lineamientos que regulan el sistema de control interno en Petróleos Mexicanos, sus empresas productivas subsidiarias y empresas filiales (Guidelines governing the internal control system of Petróleos Mexicanos, its productive subsidiary entities and affiliates) set forth the principles underlying our internal controls system and the procedures necessary for its implementation and monitoring. In addition, the Lineamientos para la participación de testigos sociales durante actividades de procura y abastecimiento y procedimiento de contratación de Petróleos Mexicanos y sus empresas productivas subsidiarias (Guidelines for the participation of public witnesses in the procurement and supply activities and contracting procedures of Petróleos Mexicanos, its productive subsidiary entities and affiliates), delineates the ways in which public witnesses may act as third-party observers in connection with our procurement procedures. These internal controls and guidelines are applicable to Petróleos Mexicanos and the subsidiary entities. For a description of the risks relating to anti-corruption, anti-bribery and anti-money laundering laws and regulations, see “Item 3—Key Information—Risk Factors—Risk Factors Related to our Operations—We are subject to Mexican and international anti-corruption, anti-bribery and anti-money laundering laws. Our failure to comply with these laws could result in penalties, which could harm our reputation, prevent us from obtaining governmental authorizations needed to carry out our operations and have an adverse effect on our business, results of operations and financial condition.”

Petróleos Mexicanos and the subsidiary entities, as public entities of the Mexican Government, are subject to the Ley General del Sistema Nacional Anticorrupción (General Law of the National Anti-corruption System), the Ley de Fiscalización y Rendición de Cuentas de la Federación (Federal Audit and Accountability Law), and the Ley General de Responsabilidades Administrativas (General Law of Administrative Liabilities), among others. These laws establish a national anti-corruption system to coordinate efforts among the Mexican Government, federal entities, states and municipalities to prevent, investigate and punish corrupt activities and oversee public resources, as well as determine administrative liabilities of public officials and the applicable penalties.

On July 14, 2017, the Board of Directors of Petróleos Mexicanos approved our “Compliance Program”, a series of procedures aimed to comply with legal, accounting, and financial provisions to prevent corruption and to promote ethical values. These procedures include a focus on internal controls, risk management, ethical principles and corporate integrity, policies promoting transparency and accountability.

On August 28, 2017, a new Código de Conducta de Petróleos Mexicanos, sus empresas productivas subsidiarias y, en su caso, empresas filiales (Code of Conduct of Petróleos Mexicanos, its productive subsidiary entities and, where applicable, affiliated companies, or the Code of Conduct) was published in the Official Gazette of the Federation, replacing the code of conduct issued in February 2015. This Code of Conduct delineates behaviors expected of and banned for our employees, in accordance with the values established in the Code of Ethics, which was also published on that same day in the Official Gazette of the Federation, approved by the Board of the Directors of Petróleos Mexicanos in November 2016, such as: respect, non-discrimination, honesty, loyalty, responsibility, legality, impartiality and integrity, among others.

On September 11, 2017, the Políticas y Lineamientos Anticorrupción para Petróleos Mexicanos, sus empresas productivas subsidiarias y, en su caso, Empresas Filiales (Anti-corruption Policies and Guidelines for Petróleos Mexicanos, its productive subsidiary entities and, where applicable, affiliated companies) and the Políticas y Lineamientos para el desarrollo de la Debida Diligencia en Petróleos Mexicanos, sus empresas productivas subsidiarias y, en su caso, Empresas Filiales, en Materia de Ética e Integridad Corporativa (Policies and Guidelines to carry out Due Diligence in Petróleos Mexicanos, its productive subsidiary entities and, where applicable, affiliated companies, in Ethics and Corporate Integrity matters) became effective. The purpose of these regulations is to set up actions against acts of corruption as well as provide means to confront and fight them and mitigate our own risks as well as third-party risks that may affect the activities of PEMEX for acts of corruption, lack of ethics or corporate integrity or our involvement in illicit acts of any kind.

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As an issuer of debt securities that are registered under the Securities Act and in connection with certain representations and covenants included in our financing agreements, we must comply with the U.S. Foreign Corrupt Practices Act, or the FCPA. The FCPA generally prohibits companies and anyone acting on their behalf from offering or making improper payments or providing benefits to government officials for the purpose of obtaining or keeping business. In addition, we are subject to other international laws and regulations related to anti-corruption, anti-bribery and anti-money laundering, including the U.K. Bribery Act 2010, which prohibits the solicitation of, the agreement to receive and the acceptance of bribes.

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ENVIRONMENTAL REGULATION

Legal Framework

We are subject to the environmental laws and regulations issued by the local and state governments where our facilities are located, including those associated with atmospheric emissions, water usage and wastewater discharge, as well as the management of hazardous and non-hazardous waste. In particular, we are subject to the provisions of the Ley General del Equilibrio Ecológico y la Protección al Ambiente (General Law on Ecological Equilibrium and Environmental Protection, which we refer to as the Environmental Law) and related regulations, the Ley General de Cambio Climático (General Law on Climate Change) and other technical environmental standards issued by the Secretaría del Medio Ambiente y Recursos Naturales (Secretariat of the Environment and Natural Resources or SEMARNAT) and the Agencia de Seguridad, Energía y Ambiente (National Agency for Industrial Safety and Environmental Protection of the Hydrocarbons Sector or ASEA). We are also subject to the Ley General para la Prevención y Gestión Integral de los Residuos (General Law on Waste Prevention and Integral Management) and the Ley de Transición Energética (Law of the Energy Transition).

In April 1997, the SEMARNAT issued regulations governing the procedures for obtaining an environmental license, under which new industrial facilities can comply with all applicable environmental requirements through a single administrative procedure. Each environmental license integrates all of the different permits, licenses and authorizations related to environmental matters for a particular facility. Since these regulations went into effect, we have been required to obtain an environmental license for any new facility. Our facilities that existed prior to the effectiveness of these regulations are not subject to this requirement.

Before we carry out any activity that may have an adverse impact on the environment, we are required to obtain certain authorizations from ASEA, the SEMARNAT, the Ministry of Energy, the National Water Commission and the Mexican Navy, as applicable. In particular, specific environmental regulations apply to petrochemical, crude oil refining and extraction activities, as well as to the construction of crude oil and natural gas pipelines. Before authorizing a new project, ASEA requires the submission of an environmental impact and risk analysis.

ASEA is an administrative body of the SEMARNAT that operates with technical and administrative autonomy and has the authority to regulate and supervise companies participating in the hydrocarbon sector through its issuance of rules establishing safety standards, limits on greenhouse gas emissions and guidelines for the dismantling and abandonment of facilities, among other things. The Ley de la Agencia Nacional de Seguridad Industrial y de Protección al Medio Ambiente del Sector Hidrocarburos (Law of the Hydrocarbons Industrial Safety and Environmental Protection Agency of the Hydrocarbon Sector) provides that until the general administrative provisions and Official Mexican Standards proposed by the Hydrocarbons Industrial Safety and Environmental Protection Agency are in effect, obligations will continue under the guidelines, technical and administrative arrangements, agreements and Official Mexican Standards promulgated by the SEMARNAT, CNH and CRE.

The environmental regulations specify, among other matters, the maximum levels of emissions and waste water discharge that are permissible. These regulations also establish procedures for measuring pollution levels, the management of hazardous and non-hazardous waste and the treatment of sites affected by hydrocarbon production.

We are also subject to the NOM-001-SEMARNAT-1996 issued by CONAGUA in conjunction with the Procuraduría Federal de Protección al Ambiente (PROFEPA), which sets forth the maximum permissible levels of pollutants in wastewater that can be discharged into national bodies of water. In addition, we are subject to the NOM-052-SEMARNAT-2006, which regulates hazardous waste, the NOM-161-SEMARNAT-2011, which regulates special waste management procedures, as well as the NOM-138-SEMARNAT/SSA1-2012, which establishes the maximum permissible levels of hydrocarbons in the soil and sets forth guidelines with respect to soil testing and the treatment of sites affected by hydrocarbon production.

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Federal and state authorities are authorized to inspect any facility to determine its compliance with the Environmental Law, local environmental laws, regulations and technical environmental regulations. Violations or non-compliance with environmental standards and regulations may result in substantial fines, temporary or permanent shutdown of a facility, required capital expenditures to minimize the effect of our operations on the environment, cleanup of contaminated soil and water, cancellation of a concession or revocation of an authorization to carry out certain activities and, in certain cases, criminal proceedings. See “Item 3—Key Information—Risk Factors—Risk Factors Related to Our Operations—Our compliance with environmental regulations in Mexico could result in material adverse effects on our results of operations.”

Mexico generally reviews and updates its environmental regulatory framework every five years , and we work with the Mexican Government to develop new environmental regulations of activities related to the oil and gas industry.

During 2016, the CNH updated the technical provisions for the use of natural gas in exploration and extraction activities and issued regulations for drilling, exploration and development.

Also in 2016, ASEA required that CONAGUA monitor water tables before we began drilling shale gas exploratory wells in the northern part of Veracruz and the southern part of Tamaulipas.

During 2016, ASEA issued further regulations that establish guidelines on, among others, implementing and authorizing industrial safety management systems, operational safety and environmental protection, as well as the reporting of incidents to the authorities. Moreover, in 2017 ASEA issued regulations for the external auditing of the performance of such safety systems.

Climate Change

On June 6, 2012, the General Law on Climate Change was published in the Official Gazette of the Federation, with the objectives of regulating greenhouse gas emissions and reducing the vulnerability of Mexico’s infrastructure, population and ecosystems to the adverse effects of climate change. The General Law on Climate Change establishes a series of financial, regulatory and technical rules and regulations, as well as tools for strategy formation, evaluation and monitoring that form the framework for a comprehensive public policy on climate change.

Our Special Climate Change Program 2014-2018 aims to reduce greenhouse gas emissions, improve energy and operational efficiency, reduce gas flaring and promote the efficient use of gas, among other things. Pursuant to this program, in 2016, we began upgrading the Ing. Antonio Dovalí Jaime Refinery in Salina Cruz, Oaxaca to operate on cleaner natural gas. We also began the test period for a cogeneration project to increase energy efficiency at the Antonio M. Amor Refinery in Salamanca, Guanajuato, and to evaluate the reduction of greenhouse gas emissions. In addition, we continue to work on our PEMEX Environmental Strategy 2016-2020, which incorporates our former Plan de Acción Climática (Climate Action Plan), to identify action items, projects and best practices to mitigate the impact of our operations on climate change. These actions include the construction of infrastructure for transportation and gas management.

We also work with several national and international entities to develop and promote initiatives that mitigate the effects of climate change. For instance, we participate in the Climate and Clean Air Coalition (CCAC), with which we aim to identify emission sources in our key facilities and substantially reduce emissions of climate pollutants. In compliance with CCAC criteria, we carried out inspections in nine facilities, including Dos Bocas, Cactus and Atasta and have mitigated the emissions identified in those inspections.

In accordance with the actions carried out by the Mexican Government to mitigate global climate change, we are analyzing the implementation of carbon capture, use and storage (CCUS) techniques. In 2014, the “Technology Route Map of CCUS in Mexico” was developed in conjunction with SENER, SEMARNAT and

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CFE. This led to the execution of integrated carbon dioxide capture projects at PEMEX and CFE facilities and enhanced oil recovery (EOR) initiatives. In 2016, several tools were developed to evaluate the first CCUS-EOR project in Mexico. This project included a plan to inject carbon dioxide produced at our Cosoleacaque Petrochemical Complex into the Brillante producing field at the Cinco Presidentes business unit. By the end of 2017, we had put in place the necessary environmental and social safeguards for the pilot projects, which in turn allows us to receive support from the World Bank.

During 2017, we recorded greenhouse gas emissions of approximately 40 million tons of carbon dioxide equivalent, which represented a 30 % decrease compared to 2016, mainly due to an increase in the use of associated gas from Kumaza, Cantarell, Abkatún Pol-Chuc and Litoral de Tabasco fields. Our gas usage level was approximately 97% during 2017, as compared to 91% in 2016, which increase was mainly due to field performance and our operational flexibility.

In 2017, we continued to develop several conservation and reforestation projects designed to increase carbon dioxide and water capture to preserve the ecosystems in which we operate. Our biodiversity conservation efforts and indirect mitigation measures have been carried out through the following projects:

• Proyecto de Conservación, Manejo y Restauración de los Ecosistemas Naturales de la Cuenca Media del Río Usumacinta (Conservation, Management and Restoration Project of the Natural Ecosystems of the Rio Usumacinta Basin) in Chiapas;

• Operación y manejo del corredor ecológico JATUSA (Operation and Management of the JATUSA Ecological Corridor) in the Jaguaroundi and Tuzandépetl ecologic parks, and the Santa Alejandrina swamp; and

• Educación Ambiental y Operación de la Casa del Agua, en los Pantanos de Centla (Environmental Education and Operation of the Casa del Agua in Pantanos de Centla) in Tabasco.

We also continued to develop the JATUSA Ecological Corridor. This project is one of our most important conservation initiatives and its purpose is to merge natural or modified spaces, ecosystems and habitats to facilitate the conservation of biodiversity. During the months of April through June of 2017, we made improvements to the Jaguaroundi Park with the goal of attracting more visitors. Additionally, by the end of 2017 we developed a business plan that encourages the participation of nearby communities to maximize profits and facilitate the preservation of biodiversity. For 2018, we plan to establish a fund to guarantee the continuing operation of this project.

Clean Development Mechanism Projects

In 2000, Mexico ratified the Kyoto Protocol to the United Nations Framework Convention on Climate Change as a non-Annex B country. Accordingly, Mexico is not subject to emission parameters under the Kyoto Protocol, but Mexican companies, such as PEMEX, are allowed to develop projects known as Clean Development Mechanism (CDM) projects. These CDM projects generate carbon dioxide emission reduction certificates or credits that can be traded in international markets. We have registered two CDM projects under the United Nations Framework Convention on Climate Change: waste energy recovery at the Dos Bocas Maritime Terminal, which increases thermal efficiency by recovering wasted heat for the Maya oil dewatering process, and the Tres Hermanos oil field gas recovery and utilization project, which involves the recovery and transportation of gas from oil wells that used to be flared from oil batteries to a new carbon dioxide separation and gas conditioning plant, where dry gas and condensates are produced. The decrease in emissions resulting from these projects is expected to be verified by a third party recognized by the United Nations.

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In addition, in November of 2017 we participated in a meeting of the Oil and Gas Climate Initiative (OGCI). This initiative is an effort by ten international oil companies, representing 20% of the total production of oil and gas in the world, to reduce emissions of greenhouse gases. The leadership of these companies endorse the Paris Agreement and the OGCI aims to reduce methane emissions, accelerate the deployment of carbon capture, use and sequestration, improve energy efficiency and contribute to transport efficiency. During this meeting, our CEO explained our strategy of reducing gas burning in the shallow water assets through the rehabilitation of compression modules and optimizing energy consumption in the refining processes.

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HEALTH, SAFETY AND ENVIRONMENTAL PERFORMANCE

We believe that we are in substantial compliance with current federal and state environmental laws and that we maintain an organizational structure designed to identify and solve environmental risks. In addition, our subsidiary entities have specialized departments that implement their own internal environmental programs, audits and facilities inspections. When these internal audits reveal problems or deficiencies, the subsidiary entities take the necessary measures to eliminate them.

In addition to our internal monitoring structure, Petróleos Mexicanos and its subsidiary entities’ environmental audit program is subject to review by ASEA, which oversees reviewing compliance with environmental regulations for the oil and gas sector and establishes environmental remediation standards.

Since 1993, we have participated in the National Environmental Audit Program (NEAP), a voluntary alternative to the traditional system of inspections and penalties, with PROFEPA and now with ASEA. This program was created by PROFEPA in 1992 as a regulatory incentive for companies to voluntarily correct any environmental irregularities in their operations.

In general terms, voluntary environmental auditing consists of three stages: (i) an audit and compliance diagnosis; (ii) development of an action plan to correct irregularities; and (iii) the implementation of the action plan. If a company satisfactorily completes these three stages, ASEA grants the audited company a clean industry certificate, which means that it complies with the applicable environmental legislation of their industry.

As of December 31, 2017, we have registered 290 of our facilities with NEAP with the objective of obtaining a “clean industry” certificate for each facility. During 2017, 123 of our facilities were re-certified and an additional 44 facilites were certified for the first time. The audits of the remaining 123 facilities are still under review. We will continue including new facilities under this program, as we expand our activities in the areas of exploration, exploitation, refining and distribution of hydrocarbons.

On February 7, 2016, a fire and explosion occurred at the Abkatun-A-Compression processing platform in the Gulf of Mexico, which activated the safety systems, procedures and protocols and the platform was evacuated. As a result of this accident, three offshore workers (two PEMEX employees and one contractor) lost their lives. The explosion was caused when the welding of an FA-4210 cap failed.

During 2017, we did not experience any major incident that had significant environmental consequences. We did, however, experience the following nine material blasts or hazardous events at our facilities, none of which had significant environmental consequences:

• On January 12, 2017, during the cleaning of the hydrodesulphurizing plant exchangers of the intermediate distillates U-501 of the Francisco I. Madero Refinery, there was a leak of sulfuric acid that killed one worker.

• On March 15, 2017, an explosion occurred at the Salamanca storage and dispatch terminal during work that was done to uncover a heavy fuel oil line. As a result of this accident three of our employees and five contractors lost their life.

• On March 23, 2017, an incident occurred at the Independencia Petrochemical Complex during railroad maneuvers. As a result of this incident, which was caused by a miscommunication between the machinist and a rail transport worker, one employee of the railroad company lost his life.

• On March 29, 2017, a fire occurred inside a barge tank located at the dock of Madero shipyards while employees were removing heating coils, resulting in minor injuries to 17 employees.

• On March 31, 2017, while fixing an illegal tap of the Mendoza pipeline, a leak and fire occurred that resulted in three workers being injured, one of whom lost his life.

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• On June 14, 2017, as a result of flooding caused by tropical storms “Beatriz” and “Calvin”, there was an explosion at our Salina Cruz refinery and subsequent fire that lasted 43 hours. As a result of this incident, one employee lost his life, the pumping house at the location of the explosion and many pipelines were destroyed and operations at the Salina Cruz refinery were temporarily suspended.

• On July 29, 2017, the driver of a fire protection unit at our Salina Cruz Maritime Storage Terminal lost control over the unit, resulting in an accident which caused two fatalities.

• On December 12, 2017, during railroad maneuvers inside our Salamanca Refinery, an employee of the railroad company fell down the convoy, resulting in his death.

• On December 14, 2017, during maintenance and cleaning activities at the alkylation plant at our Madero Refinery, there was a leak of hydrofluoric acid, causing the maintenance supervisor to suffer chemical burns and ultimately lose his life.

As part of our accident prevention strategy, we conduct root cause investigations of all incidents that occur during our operations. These investigations allow us to identify the causes and establish corrective measures to avoid the recurrence of such type of incident.

In 2017, our lost time injury rate decreased 5.6% from 0.36 in 2016 to 0.34 in 2017. The segment that contributed most to this decrease was the industrial transformation segment. Our lost days indicator due to injuries decreased 8.7% from 23 to 21 lost days per million man hours worked with risk exposure from 2016 to 2017. Lost days are those missed as a result of incapacitating injuries suffered at work or those on which compensation is paid for partial, total or permanent incapacity or death. From 2016 to 2017, our contractors’ lost time injury rate decreased 65.4% from 0.26 to 0.09 injuries per million man-hours worked with risk exposure.

In 2017, our primary initiatives in industrial safety, health and environmental protection included the following:

• Weekly visits to subsidiary facilities to supervise the implementation of the PEMEX-SSPA System;

• Review of compliance with our 12 zero tolerance EH&S guidelines;

• Verification and advice in the application of the eight critical standards of process safety;

• Evaluation of our Binomio project for the immediate verification and mitigation of risks;

• EH&S campaigns, including the “Order and Cleaning”, “Prevention of Falls at the Same Level” and the “Up the Voice, All Safe, All Aboard” campaigns to ensure that platform workers are in optimal health;

• Several EH&S campaigns aimed at creating awareness of the importance of, and reinforcing a commitment to, equipment protection; and

• EH&S leadership evaluations at the three levels of the organization (strategic, tactical and operational).

On May 19, 2017, Pemex Exploration and Production received an award for high performance from ASEA for achieving the lowest lost time injury frequency rate in its history in 2016, with 0.25 injuries per million man-hours worked, 45% lower than 2015. In 2017, this index was 0.34 for PEMEX as a whole, which represents a decrease of 5.6% compared to 2016.

By the end of 2017, we finished the design of the new model of the PEMEX-SSPA System, which works to incorporate international best practices and includes the International Association of Oil and Gas Producers (IOGP) standards. The Pemex-SSPA System was approved by ASEA, which allows us to operate our facilities in accordance with the energy reform.

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Environmental Liabilities

As of December 31, 2017, our estimated and accrued environmental liabilities totaled Ps. 17,482.4 million. Of this total, Ps. 755.9 million belong to Pemex Exploration and Production, Ps. 2,680.8 million to Pemex Industrial Transformation and Ps. 14,045.8 million to Pemex Logistics. The following tables detail our environmental liabilities by subsidiary entity and operating region at December 31, 2017.

Pemex Exploration and Production⁽¹⁾

	Estimated Affected Area		Estimated Liability
	(in hectares)		(in millions of pesos)
Northern region		150.42	Ps.	359.0
Southern region		159.14		250.7
Total(2)		309.56	Ps.	609.6

Note: Numbers may not total due to rounding.

(1) Includes all liabilities of Pemex Exploration and Production that were assumed pursuant to our corporate reorganization.

(2) During 2017, environmental remediation was completed on 66.36 hectares. There were 154.65 hectares of additional affected areas in 2016, as a result of spills from pipelines mainly.

Source: PEMEX.

	Holding Ponds Drainage
	Number of Holding Ponds Reported as Liabilities(1)		Estimated Liability
			(in millions of pesos)
Southern region		11	Ps.	19.3
Northern region		69		127.0
Total		80	Ps.	146.2
Total estimated environmental liabilities of Pemex Exploration and Production			Ps.	755.9

Note: Numbers may not total due to rounding.

(1) In 2017, no new ponds were added, and no holding ponds were restored. As a result, as of December 31, 2017, 80 ponds remain to be reported.

Source: Pemex Exploration and Production.

Pemex Industrial Transformation

	Estimated Affected Area		Estimated Liability
	(in hectares)		(in millions of pesos)
Refineries		285.49		Ps. 2,661.3
Reynosa Gas complex processor		11.52		19.5
Total estimated environmental liabilities of Pemex Industrial Transformation		297.01		Ps 2,680.8

Note: Numbers may not total due to rounding.

Source: Pemex Industrial Transformation.

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Pemex Logistics

	Estimated Affected Area		Estimated Liability
	(in hectares)		(in millions of pesos)
Storage and Distribution Terminals		69.58	Ps.	919.0
Pipelines		989.59		13,126.8
Total estimated environmental liabilities of Pemex Logistics		1,059.17	Ps.	14,045.8

Note: Numbers may not total due to rounding.

Source: Pemex Logistics.

Our estimates of environmental liabilities include cost estimates for site-specific evaluation studies, which draw upon aspects of previous evaluations for sites with comparable characteristics and the corresponding remediation. The remediation sites consist of facilities identified in the audit process described above, as well as those previously identified sites in more mature petroleum operating areas that were not cleaned up in the past. Our environmental liabilities also include the elimination of holding ponds created by abandoned petroleum wells. Additionally, our environmental liabilities include an accrual based on information received periodically from field managers regarding probable environmental liabilities identified in their respective areas of responsibility. We accrue environmental liabilities when sufficient basic knowledge is available to form a preliminary estimation as to remediation cost. Although the full potential scope of the remediation cost may not be known with certainty, these accruals are made when the liability is probable and the amount may be reasonably estimated, in accordance with IAS 37 “Provisions, Contingent Liabilities and Contingent Assets” for IFRS purposes. These estimated liabilities include assumptions resulting from an initial evaluation of damage, including land acreage to be remediated, depth and type of contamination. While the initial evaluation is extensive, there is a possibility that the actual scope of remediation could vary depending upon information gathered during the remediation process. For a further discussion of our environmental liabilities, see Note 3(l) to our consolidated financial statements included herein.

Unasserted or additional claims are not reflected in our identified liabilities. We are not aware of any such claims that would be of such magnitude as to materially affect our estimates of environmental liabilities. At the end of 2017, we were not aware of uncertainties with respect to joint and several liabilities that could affect our assessment of environmental contingencies or otherwise result in a major environmental liability. See “—History and Development—Energy Reform” above in this Item 4 for more information regarding the participation of other companies in the Mexican energy sector. As a result, we believe we are positioned to know immediately of any claims and are therefore directly accountable for any claims that may be brought against us.

Pemex Exploration and Production remains responsible for handling existing environmental liabilities—these responsibilities are not part of the Integrated E&P Contracts. Nevertheless, the Integrated E&P Contracts include environmental clauses related to contractors’ and Pemex Exploration and Production’s responsibility to ensure an adequate environmental performance, and also establish the terms for compensation and repair of any new environmental impacts.

The timing of remediation or cleanup of the sites to which these environmental liabilities relate is dependent upon the annual budget approved by the Mexican Congress.

On August 1, 2017, we were granted a favorable judgment by the Supreme Court of Justice of the Nation, which determined that we are not liable for material and environmental damages caused by hydrocarbons spills related to illegal tapping of pipelines, since the environmental damage was caused by third party criminal behavior.

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Environmental Projects and Expenditures

In 2017, we spent approximately Ps. 5,760 million on environmental projects and related expenditures, as compared to Ps. 11,424 million in 2016. For 2018, we have budgeted Ps. 3,473 million for environmental projects and expenditures, including modernization of installations, implementation of systems and mechanisms to monitor and control atmospheric pollution, acquisition of equipment to address contingencies related to oil and gas spills, the expansion of water effluent systems, restoration and reforestation of affected areas, studies for environmental investigation and environmental audits. In addition, we continue to conduct research and development efforts to increase our capacity to produce gasoline, diesel and fuel oil with lower sulfur content at our refineries in Mexico.

We do not believe that the cost of complying with environmental laws or environmental requirements related to the NAFTA among the governments of Mexico, the United States and Canada, the Vienna Convention for the Protection of the Ozone Layer, the Agreement on Environmental Cooperation between the Governments of Mexico and Canada or Mexico’s membership in the Organization for Economic Cooperation and Development, has caused or will cause a significant increase in our environmental expenditures.

Social Responsibility

We have implemented various corporate social responsibility initiatives, primarily with respect to the protection and preservation of the environment, relations with communities where we operate, ethical work practices, respect for labor rights and the general promotion of quality of life for communities and employees.

Our corporate and social responsibility goals are carried out through the following mechanisms:

• cash donations;

• product donations of fuels and asphalt;

• donations of movable and immovable property;

• environmental protection projects;

• mutually beneficial public works, which are projects we carry out in collaboration with local authorities and communities to improve infrastructure that is beneficial both to us and to the community;

• the Programa de apoyo a la comunidad y medio ambiente (Program to support communities and the environment, which we refer to as PACMA), which supports and implements social programs, actions and public works designed to promote the economic and social development of the communities in which we operate and to protect their environment; and

• other instruments that provide a positive impact on communities, including integrated exploration and production contracts and the sustainable development annexes and clauses to our contracts, in which we and our contractors commit to improving the quality of life in communities where we operate.

In 2017, the total value of our donations and contributions amounted to Ps. 1,670.3 million. Our cash donations amounted to approximately Ps. 59.0 million, our asphalt and fuel donations amounted to approximately Ps. 1,247.0 million and our movable and immovable property donations amounted to approximately 17.0 million. Contributions made through provisions of our Integrated E&P Contracts, FPWCs, SD Annexes and RS KMZ sustainable development clause amounted to Ps. 90.5 million, and PACMA and mutual benefit project contributions amounted to Ps. 233.8 million and Ps. 23.0 million, respectively.

Approximately 92.4% of our donations and contributions were assigned to 12 states with greater activity in the oil and gas industry (Campeche, Chiapas, Coahuila, Guanajuato, Hidalgo, Nuevo León, Oaxaca, Puebla, San

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Luis Potosí, Tabasco, Tamaulipas and Veracruz)); and the remaining 7.6% to the remaining states. Most importantly, we took the following specific actions in 2017:

• contributed approximately Ps. 894.8 million in fuel for the operation of vehicles and machinery for various state and municipal governments, principally to provide assistance for emergencies, civil protection programs, services and public safety;

• contributed approximately Ps. 326.5 million to the construction, improvement or pavement of roads and highway infrastructure in 23 states;

• contributed approximately Ps. 98.9 million toward education and sports programs in oil and gas communities in 6 states, mainly for scholarships and the construction of schools and sports facilities;

• contributed approximately Ps. 41.3 million for environmental education, restoration and conservation of protected natural areas through programs implemented in the states of Campeche, Chiapas, Tabasco and Veracruz;

• contributed approximately Ps. 25.7 million in turbosine for the operation of state aircrafts in the states of Campeche, Chiapas, Hidalgo and Veracruz; and

• contributed approximately Ps. 15.7 million towards sustainability projects and training programs primarily aimed at fishing communities in the states of Oaxaca and Tabasco.

In addition, we made the following donations under our PACMA program:

• contributed approximately Ps. 82.4 million for the operation of mobile medical units and other medical services in the state of Tabasco;

• contributed approximately Ps. 33.5 million for the installation of public lighting in communities in the states of Campeche, Guanajuata, Oaxaca and Veracruz;

• contributed approximately Ps. 16.3 million for the construction and restoration of public parks and sports facilities in communities in the states of Campeche, Nuevo León, Tabasco and Veracruz; and

• contributed approximately Ps. 7.0 million for the construction of community kitchens in eight municipalities in the states of Oaxaca and Veracruz.

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TRADE REGULATION AND EXPORT AGREEMENTS

Though Mexico is not a member of Organization of the Petroleum Exporting Countries (which we refer to as OPEC), it has periodically announced increases and decreases in our crude oil exports reflecting production revisions made by other oil producing countries, in order to contribute to crude oil prices stabilization. However, we have not changed our export goals because of announcements made by OPEC since 2004, and we believe that Mexico has no current plans to change our current level of crude oil exports.

NAFTA has not affected Mexico’s rights, through us or other companies, to explore and exploit crude oil and natural gas in Mexico, to refine and process crude oil and natural gas and to produce petrochemicals in Mexico. Since 2003, petrochemical products have enjoyed a zero tariff under NAFTA and, subject to limited exceptions, exports of crude oil and petroleum products from Mexico to the United States and Canada have been free or exempt from tariffs. Similarly, since 2003, Mexico’s imports of petroleum products from the United States and Canada have also been exempt from tariffs. In addition, in 2004, NAFTA approved lower tariffs on certain materials and equipment imported by Mexico. The zero tariff on Mexico’s imports of petrochemicals from the United States and Canada could have increased competition in the petrochemicals industry in Mexico. To the extent that domestic and international prices for our products remain constant, lower tariffs on products, materials and equipment that we import from and export to the United States and Canada, reduce our expenses and increase our revenue.

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TAXES, DUTIES AND OTHER PAYMENTS TO THE MEXICAN GOVERNMENT

General

Taxes and duties applicable to us are a significant source of revenues to the Mexican Government. We contributed approximately 8.6% of the Mexican Government’s revenues in 2016 and 11.3% in 2017. In 2017, we paid a number of special oil and gas taxes and duties, in addition to the other taxes and duties paid by some of the subsidiary companies, as described below under “—Other Taxes.” The fiscal regime in effect for Petróleos Mexicanos and the subsidiary entities for 2017 (which we refer to as the fiscal regime) became effective in 2015 and can be subsequently modified from time to time. The Secondary Legislation published in August 2014 set forth a fiscal regime applicable to the new contractual arrangements that governs exploration and production activities conducted in Mexico beginning on January 1, 2015, as well as a new state dividend to be paid by Petróleos Mexicanos and the subsidiary entities beginning on January 1, 2016. See “—Fiscal Regime” and “—Other Payments to the Mexican Government” below.

Fiscal Regime for PEMEX

Fiscal Regime

The Hydrocarbons Revenue Law that was adopted as part of the Secondary Legislation sets forth, among other things, the following duties applicable to us in connection with our assignments granted by the Mexican Government:

• Derecho por la Utilidad Compartida (Profit-Sharing Duty): As of January 1, 2015, this duty is equivalent to 70% of the value of oil and gas produced in the relevant area, less certain permitted deductions. Pursuant to the Hydrocarbons Revenue Law, this duty is to decrease on an annual basis until January 1, 2019, at which point it will be set at 65%. During 2017, we paid Ps. 373,728 million in connection with this duty, a 22.8% increase from Ps. 304,299 paid in 2016, primarily resulting from an increase in oil and gas prices. On August 18, 2017, a decree was published in the Official Gazette of the Federation that increased the amount we can deduct for investments, costs and expenses made pursuant to this duty and resulted in a benefit of Ps. 7,770 million. On November 30, 2017, the decree entitled Acuerdo por el que se reforman y adicionan diversas disposiciones de las Reglas de carácter general para definir los métodos de ajuste del valor de los hidrocarburos de los derechos sobre hidrocarburos (Agreement by which various provisions of the general rules are reformed and added to define the methods of adjusting the value of hydrocarbons and hydrocarbon rights) was published in the Official Gazette of the Federation, defining the method for adjusting the value of hydrocarbons, which resulted in an estimated tax benefit of Ps. 8,854 million. In addition, we received a benefit of Ps. 2,187 million in the payment of this duty as a result of adjustments to the fair economic value of certain exploration and production areas. See “Item 5—Critical Accounting Policies—Exploration and Production Taxes and Duties” below.

• Derecho de Extracción de Hidrocarburos (Hydrocarbons Extraction Duty): This duty is to be determined based on a rate linked to the type of hydrocarbons (e.g., crude oil, associated natural gas, non-associated natural gas or condensates), the volume of production and the relevant market price. During 2017, we paid Ps. 58,523.1 million under this duty, a 32% increase from Ps. 43,517.4 million in 2016, mainly due to an increase in oil and gas prices.

• Derecho de Exploración de Hidrocarburos (Exploration Hydrocarbons Duty): The Mexican Government is entitled to collect a monthly payment of Ps. 1,214 per square kilometer of non-producing areas. After 60 months, this duty increases to Ps. 2,904 per square kilometer for each additional month that the area is not producing. These amounts will be updated on an annual basis in accordance with the national consumer price index (NCPI). During 2017, we paid Ps. 981 million under this duty, a 1.8% decrease from Ps. 963 million in 2016.

• In 2016, Mexican companies paid a corporate income tax at a rate of 30% applied to revenues, less certain deductions. Beginning in 2015, Petróleos Mexicanos and the subsidiary entities became subject

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to the Ley del Impuesto sobre la Renta, or Mexican Income Tax Law. During 2017, we did not pay any tax under this law, as compared to the Ps. 1,333 million we paid in 2016.

Under the 2017 fiscal regime, some of our products are subject to the following IEPS Taxes, which we withhold from our customers and pay to the tax authorities. The IEPS tax is no longer included in our sales or expenses.

• IEPS sobre la venta de los combustibles automotrices (IEPS Tax on the Sale of Automotive Fuels): This tax is a fee on domestic sales of automotive fuels, gasoline and diesel, that Pemex Industrial Transformation collects on behalf of the Mexican Government. The applicable fees for this tax are Ps. 4.30 per liter of Magna gasoline; Ps. 3.64 per liter of Premium gasoline and Ps. 4.73 per liter of diesel. The amount of the fee will depend on the class of fuel, and is fixed monthly by the Ministry of Finance and Public Credit. The fees apply to sales in Mexico and imports, and are not subject to VAT.

• IEPS beneficio de entidades federativas, municipios y demarcaciones territoriales (IEPS Tax in Favor of States, Municipalities and Territories): This tax is a fee on domestic sales of automotive fuels, gasoline and diesel, that Pemex Industrial Transformation collects on behalf of the Mexican Government. The applicable fees for this tax are 38 cents per liter of Magna gasoline, 46.37 cents per liter of Premium gasoline and 31.54 cents per liter of diesel. This fee changes yearly in accordance with inflation. Funds gathered by this fee are allocated to Mexican states and municipalities as provided for in the Ley de Coordinación Fiscal (Tax Coordination Law). The fees only apply to sales in Mexico and are not subject to VAT.

• IEPS a los combustibles fósiles (IEPS Tax on Fossil Fuels): This tax is a fee on domestic sales of fossil fuels that Pemex Industrial Transformation collects on behalf of the Mexican Government. The applicable fees for this tax are 6.50 cents per liter for propane, 8.42 cents per liter for butane, 11.41 cents per liter for gasoline and aviation gasoline, 13.64 cents per liter for jet fuel and other kerosene, 13.84 cents per liter for diesel, 14.78 cents per liter for fuel oil and Ps. 17.15 per ton for petroleum coke. This fee changes yearly in accordance with inflation and applies to imports to Mexico.

The Hydrocarbons Revenue Law also establishes the fiscal terms to be applied to the contracts for exploration and production granted by the Mexican Government to us or to other companies in connection with future competitive bidding rounds. Specifically, these fiscal terms contemplate the following taxes, duties, royalties and other payments to the Mexican Government (in addition to any taxes owed pursuant to the Ley de Ingresos de la Federación (Federal Revenue Law) for the applicable year and other applicable tax laws):

• Cuota Contractual para la Fase Exploratoria (Exploration Phase Contractual Fee): During the exploration phase of a project governed by a license, production-sharing contract or profit-sharing contract, the Mexican Government is entitled to collect a monthly payment of Ps. 1,214 per square kilometer of non-producing areas. After 60 months, this fee increases to Ps. 2,904 per square kilometer for each additional month that the area is not producing. The fee amount will be updated on an annual basis in accordance with the NCPI.

• Regalías (Royalties): Royalty payments to the Mexican Government are determined based on the “contractual value” of the relevant hydrocarbons, which is based on a variety of factors, including the type of underlying hydrocarbons (e.g., crude oil, associated natural gas, non-associated natural gas or condensates), the volume of production and the market price. Royalties are payable in connection with licenses, production-sharing contracts and profit-sharing contracts.

• Pago del Valor Contractual (Contractual Value Payment): Licenses require a payment calculated as a percentage of the “contractual value” of the hydrocarbons produced, as determined by the Ministry of Finance and Public Credit on a contract-by-contract basis.

• Porcentaje a la Utilidad Operativa (Operating Profit Payment): Production-sharing contracts and profit-sharing contracts require a payment equivalent to a specified percentage of operating profits. In

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the case of production-sharing contracts, this payment is to be made in-kind through delivery of the hydrocarbons produced. In the case of profit-sharing contracts, this payment is to be made in cash.

• Bono a la Firma (Signing Bonus): Upon execution of a license or migration of an assignment, a signing bonus is to be paid to the Mexican Government in an amount specified by the Ministry of Finance and Public Credit.

• Impuesto por la actividad de Exploración y Extracción de Hidrocarburos (Hydrocarbons Exploration and Extraction Activities Tax): Contracts for exploration and extraction and assignments granted by the Mexican Government will include a specified tax on the exploration and extraction activities carried out in the relevant area. A monthly tax of Ps. 1,584 per square kilometer is payable during the exploration phase until the extraction phase begins. During the extraction phase of a project, a monthly tax of Ps. 6,335 per square kilometer is payable until the relevant contract for exploration and extraction or assignment is terminated.

Under the Hydrocarbons Revenue Law, exploration and production activities associated with contracts for exploration and production are not subject to a value added tax.

Fluctuating crude oil price levels directly affect the level of certain taxes and duties that we pay. See “Item 3—Key Information—Risk Factors—Risk Factors Related to our Relationship with the Mexican Government—We pay significant taxes and duties to the Mexican Government, and, if certain conditions are met, to pay a state dividend, which may limit our capacity to expand our investment program or negatively impact our financial condition generally.”

Other Payments to the Mexican Government

Pursuant to the Petróleos Mexicanos Law, as of January 1, 2016, Petróleos Mexicanos and the subsidiary entities are required to pay a state dividend to the Mexican Government on an annual basis. In July of each year, Petróleos Mexicanos and the subsidiary entities are required to provide the Ministry of Finance and Public Credit a report disclosing their financial results for the previous fiscal year and their investment and financing plans for the following five years, together with an analysis of the profitability of these investments and the relevant projections of their financial positions. The Ministry of Finance and Public Credit will rely on this report and a favorable opinion issued by a technical committee of the Mexican Petroleum Fund for Stabilization and Development to determine the amount of the state dividend to be paid by Petróleos Mexicanos and each of the subsidiary entities. The Petróleos Mexicanos Law provides that the aggregate amount of the state dividend to be paid in 2016 is to be equal to, at minimum, 30% of the total revenues of Petróleos Mexicanos and the subsidiary entities, after taxes, from the previous fiscal year. It further provides that that percentage will decrease in subsequent years, until reaching 15% in 2021 and 0% in 2026. In accordance with the Federal Revenue Law for 2016, the Federal Revenue Law for 2017 and the Federal Revenue Law for 2018, Petróleos Mexicanos was not required to pay a state dividend in 2016 and 2017 and will not be required to pay a state dividend in 2018.

The following table sets forth the taxes and duties that we recorded for each of the past three years.

	Year ended December 31,
	2015			2016			2017
	(in millions of pesos)(1)
Hydrocarbon extraction duties and others		Ps. 377,087			Ps. 277,162			Ps. 338,044
Income tax		(45,587	)		(12,640	)		(5,064	)
Total		Ps. 331,500			Ps. 264,522			Ps. 332,980

Note: For a description of these taxes and duties, see “Item 4—Information on the Company—Taxes, Duties and Other Payments to the Mexican Government.”Numbers may not total due to rounding.

(1) Figures are stated in nominal pesos.

Source: PEMEX’s audited financial statements, prepared in accordance with IFRS.

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Other Taxes

Since 1994, our interest payments on our external debt have been subject to Mexican Government withholding taxes. Nevertheless, withholding taxes do not represent a substantial portion of our total tax liability.

We are subject to municipal and state taxes, such as real property and payroll taxes. However, because most of our facilities are located on federal property, which is not subject to municipal taxation, real property taxes are not a significant part of our overall taxes. Similarly, payroll taxes do not represent a substantial portion of our total tax liability.

In addition, we have a number of non-Mexican subsidiary companies that may be subject to taxation in the jurisdiction of their incorporation or operations. The aggregate taxes paid by the subsidiary companies were Ps. 6,833.4 million in 2015, Ps. 7,200.9 million in 2016 and Ps. 2,536.3 million in 2017.

No assurance can be given that our tax regime will not change in the future. See “Item 3—Key Information—Risk Factors—Risk Factors Related to our Relationship with the Mexican Government—We pay significant taxes and duties to the Mexican Government, and, if certain conditions are met, to pay a state dividend, which may limit our capacity to expand our investment program or negatively impact our financial condition generally.”

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UNITED MEXICAN STATES

The information in this section with regard to Mexico has been derived from publicly available information published by, or on the websites of, the Comisión Nacional Bancaria y de Valores (National Banking and Securities Commission), Banco de México (the Mexican central bank), the Ministry of Finance and Public Credit and the Instituto Nacional de Estadística y Geografía (INEGI).

Form of Government

The President of Mexico (or the President) is the chief of the executive branch of the Mexican Government. The President is elected by the popular vote of Mexican citizens who are eighteen years of age or older. The Mexican Constitution limits the President to one six-year term; the President may not run for reelection. In accordance with Mexico’s electoral law, on August 31, 2012, the Tribunal Electoral del Poder Judicial de la Federación (Federal Electoral Court) officially validated the results of the presidential election held in Mexico on July 1, 2012, and declared Mr. Enrique Peña Nieto, a member of the Partido Revolucionario Institucional (Institutional Revolutionary Party, or PRI), President-elect. Mr. Enrique Peña Nieto took office on December 1, 2012 and his term will expire on November 30, 2018.

From 1929 to 1994, the PRI won all presidential elections, and, from 1929 until July 1997, the PRI held a majority of the seats in both chambers of the Mexican Congress. From 1929 until 1989, the PRI also won all of the state gubernatorial elections. In July 2000, the candidate from the Alianza por el Cambio (Alliance for Change), a coalition of the Partido Acción Nacional (National Action Party, or PAN), the oldest opposition party in the country, and the Partido Verde Ecologista de México (Ecological Green Party), won the presidential election.

Each of Mexico’s 31 states is headed by a state governor. Mexico’s Federal District, Mexico City, is headed by an elected mayor.

Legislative authority is vested in the Mexican Congress, which is composed of the Senate and the Chamber of Deputies. Members of the Mexican Congress are elected either directly or through a system of proportional representation by the popular vote of Mexican citizens who are 18 years of age or older. The Senate is composed of 128 members, 96 of whom are elected directly, while the other 32 are elected through a system of proportional representation. The Chamber of Deputies is composed of 500 members, 300 of whom are elected directly by national electoral districts, while the other 200 are elected through a system of proportional representation. Under this proportional representation system, seats are allocated to political party representatives based on the proportion of the votes cast for those parties that receive at least 3.0% of the national vote, among other requirements.

The Mexican Constitution provides that the President may veto bills and that the Mexican Congress may override such vetoes with a two-thirds majority vote of each chamber.

Senators serve a six-year term and deputies serve a three-year term. Federal deputies are eligible for immediate reelection for up to four term periods and senators are eligible for immediate reelection for up to two term periods. Congressional elections for all 500 seats in the Chamber of Deputies were last held on June 7, 2015. The following table provides the distribution as of September 1, 2017 of Congressional seats, reflecting certain post-election changes in the party affiliations of certain senators and deputies.

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Party Representation in the Mexican Congress

	Senate					Chamber of Deputies
	Seats		% of Total			Seats		% of Total
Institutional Revolutionary Party		55		43.0	%		197		39.4	%
National Action Party		38		29.7			109		21.8
Democratic Revolution Party		18		6.2			54		10.8
Ecological Green Party of Mexico		7		5.5			48		9.6
Social Encounter Party		0		0			9		1.8
Labor Party		15		11.7			0		0.0
Citizen Movement Party		0		0.0			21		4.2
New Alliance Party		0		0.0			12		2.4
Unaffiliated Independent		5 0		3.9 0			3 1		0.6 0.2
National Regeneration Movement (New)		0		0			46		9.2
Total		128		100.0	%		500		100.0	%

Note: Numbers may not total due to rounding. According to official sources, there is one vacant seat in the Senate.

Source: Senate and Chamber of Deputies.

The Economy

General

According to World Bank data, the Mexican economy, as measured by 2016 gross domestic product (GDP) (at current prices in U.S. dollars), is the 15th largest in the world. The Mexican economy had a real GDP of Ps. 1,046.0 billion in 2016 and a decrease in GDP of Ps. 141.0 billion between 2012 and 2016.

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Gross Domestic Product

The following table sets forth the percentage change in Mexico’s real GDP by economic sector in percentage terms for the periods indicated.

Real GDP Growth by Sector

(% change against prior years)⁽¹⁾

	2012			2013			2014			2015			2016			Third quarter (annualized) 2017(2)(3)
GDP		4.0	%		1.4	%		2.3	%		2.6	%		2.3	%		2.2	%
Primary activities:
Agriculture, forestry, fishing, hunting and livestock(4)		7.4			0.9			4.3			1.6			3.6			2.2
Secondary Activities:
Mining		0.9			(0.1	)		(1.4	)		(4.6	)		(6.4	)		(10.1	)
Utilities		2.1			0.5			8.2			2.3			3.3			(0.3	)
Construction		2.5			(4.8	)		2.0			2.5			1.8			(1.2	)
Manufacturing		4.1			1.2			4.2			2.6			1.3			3.4
Tertiary Activities:
Wholesale and retail trade		4.8			2.2			3.1			4.8			2.4			3.2
Transportation and warehousing		4.1			2.4			3.2			4.3			2.8			3.2
Information		16.3			5.0			0.2			7.8			10.1			6.9
Finance and insurance		7.7			10.4			(0.8	)		4.3			7.7			9.0
Real estate, rental and leasing		2.5			1.0			2.1			2.5			1.9			2.4
Professional, scientific and technical services		1.1			1.2			1.7			4.2			7.0			1.5
Management of companies and enterprises		8.6			(1.8	)		7.2			3.5			4.7			2.2
Administrative support, waste management and remediation services		4.4			4.3			(0.2	)		1.2			4.1			5.4
Education services		2.2			0.8			0.1			0.0			1.0			(0.1	)
Health care and social assistance		2.1			0.6			(0.6	)		(2.3	)		1.3			2.7
Arts, entertainment and recreation		2.9			3.4			(1.5	)		3.8			5.7			3.1
Accommodation and food services		5.4			1.8			2.9			5.8			3.8			4.2
Other services (except public administration)		3.3			2.1			1.7			2.4			5.8			0.9
Public administration		3.7			(0.5	)		1.9			2.7			0.0			0.4

Note: Numbers may not total due to rounding.

(1) For 2012, 2013, 2014, 2015 and 2016, figures based on GDP calculated in constant pesos with purchasing power as of December 31, 2008. For the third quarter of 2017, figures based on GDP calculated in constant pesos with purchasing power as of December 31, 2013.

(2) Preliminary figures.

(3) Annualized. Actual third quarter data has been annualized by multiplying it by four. It is provided for comparison purposes only and is not necessarily indicative of performance for the full fiscal year.

(4) GDP figures relating to agricultural production set forth in this table and elsewhere herein are based on figures for “agricultural years,” with the definition of the relevant “agricultural year” varying from crop to crop based on the season during which it is grown. Calendar year figures are used for the other components of GDP.

Source: INEGI.

According to preliminary figures, Mexico’s GDP increased by 2.2% in real terms during the first nine months of 2017, as compared to the same period of 2016. This increase reflects increases in both primary and tertiary activities which compensated for a decrease in secondary activities.

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Employment and Labor

According to preliminary Tasa de Desocupación Abierta (open unemployment rate) figures, Mexico’s unemployment rate was 3.6% as of September 30, 2017, a 0.1 percentage point increase from the rate registered on December 31, 2016. As of September 30, 2017, the economically active population in Mexico fifteen years of age and older consisted of 54.4 million individuals.

The new minimum wage of Ps. 88.36 per day, as set by the Comisión Nacional de los Salarios Mínimos (National Minimum Wage Commission) on November 21, 2017, went into effect on December 1, 2017 and was applied uniformly across Mexico.

Principal Sectors of the Economy

Manufacturing

The following table sets forth the change in industrial manufacturing output by sector for the periods indicated.

Industrial Manufacturing Output Differential by Sector

(% change against prior years)⁽¹⁾

	2012			2013(2)			2014(2)			2015(2)			2016(2)			Third quarter of 2017(2)
Food		2.6	%		0.9	%		0.7	%		1.7	%		2.6	%		1.9	%
Beverage and tobacco products		2.6			(0.5	)		3.1			4.9			5.2			1.9
Textile mills		3.1			(2.7	)		(1.7	)		3.9			(0.7	)		0.1
Textile product mills		(0.1	)		3.5			7.0			9.8			4.1			(14.1	)
Apparel		(0.5	)		3.3			(2.8	)		7.2			(2.0	)		0.3
Leather and allied products		3.5			(0.6	)		(1.7	)		2.4			(1.6	)		(1.8	)
Wood products		13.0			(2.2	)		1.0			3.6			(4.8	)		7.0
Paper		4.8			2.1			3.1			3.9			3.4			2.7
Printing and related support activities		(4.1	)		(6.9	)		(2.7	)		1.7			(2.9	)		(2.0	)
Petroleum and coal products		1.1			3.3			(4.5	)		(7.5	)		(11.2	)		(16.3	)
Chemicals		(0.3	)		0.8			(1.3	)		(3.0	)		(2.8	)		(2.4	)
Plastics and rubber products		9.0			(1.9	)		6.5			3.4			3.2			4.3
Nonmetallic mineral products		2.3			(3.1	)		2.8			4.9			2.8			(1.0	)
Primary metals		3.8			2.3			8.1			(4.1	)		3.3			1.0
Fabricated metal products		3.9			(3.3	)		8.1			2.9			3.3			1.9
Machinery		5.5			0.2			1.7			(0.3	)		3.3			9.4
Computers and electronic products		0.5			3.6			11.2			7.0			6.1			7.9
Electrical equipment, appliances and components		1.7			(2.0	)		9.0			6.2			3.6			2.1
Transportation equipment		13.9			5.8			12.6			7.1			0.2			10.8
Furniture and related products		2.8			(5.8	)		(1.8	)		7.8			(3.4	)		(5.7	)
Miscellaneous		0.4			0.0			6.3			4.9			3.3			5.8
Total expansion/contraction		4.1			1.2			4.2			2.6			1.3			3.4

(1) For 2012, 2013, 2014, 2015 and 2016, percent change against prior years. Percent change reflects differential in constant pesos with purchasing power as of December 31, 2008. For the third quarter of 2017, percent change against corresponding period of prior year. Percent change reflects differential in constant 2013 pesos.

(2) Preliminary figures.

Source: INEGI.

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Financial System

Monetary Policy, Inflation and Interest Rates

Banco de México’s M1 monetary aggregate consists of bills and coins held by the public, plus: (1) checking accounts denominated in local currency and foreign currency; (2) interest-bearing deposits denominated in pesos and operated by debit cards; and (3) savings and loan deposits. M2 consists of M1, plus: (1) bank deposits; (2) Government-issued securities; (3) securities issued by firms and non-bank financial intermediaries; and (4) Government and INFONAVIT liabilities related to the Retirement Savings System. M3 consists of M2, plus financial assets issued in Mexico and held by non-residents. M4 consists of M3, plus deposits abroad at foreign branches and agencies of Mexican banks.

The following table shows Mexico’s M1 and M4 money supply aggregates at each of the dates indicated.

Money Supply

	December 31,										September 30
	2012		2013		2014		2015		2016		2017(1)
	(in millions of nominal pesos)
M1:
Bills and coins		Ps.734,034		Ps.792,928		Ps.928,777		Ps.1,088,106		Ps.1,262,735		Ps.1,227,837
Checking deposits
In domestic currency		979,413		1,082,702		1,170,381		1,301,904		1,475,811		1,448,144
In foreign currency		163,611		189,020		232,467		333,094		469,185		516,892
Interest-bearing peso deposits		393,231		438,012		534,973		614,312		647,414		651,458
Savings and loan deposits		9,760		11,097		12,598		14,560		17,332		18,908
Total M1		Ps.2,280,049		Ps.2,513,758		Ps.2,879,196		Ps.3,351,975		Ps.3,872,477		Ps.3,863,239
M4		Ps.10,684,898		Ps.11,658,729		Ps.13,107,550		Ps.13,858,271		Ps.14,970,234		Ps.15,830,848

Note: Numbers may not total due to rounding.

(1) Preliminary figures.

Source: Banco de México.

Consumer inflation for the first nine months of 2017 was 5.9%, which was above the 3.0% (+/- 1.0%) target inflation for the year and 3.1 percentage points higher than the 2.8% consumer inflation for 2016. This was mainly a combined result of the adjustment of energy prices, particularly the liberalization of gasoline prices, exchange rate changes, higher agricultural prices and the increase in the minimum wage.

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The following table shows, in percentage terms, the changes in price indices and annual increases in the minimum wage for the periods indicated.

Changes in Price Indices

	National Producer Price Index(1)(2)(3)(4)		National Consumer Price Index(1)(5)		Increase in Minimum Wage
2012		1.8		3.6		4.6
2013		1.6		4.0		3.9
2014		3.3		4.1		3.9
2015		2.8		2.1		6.9
2016		8.5		3.4		4.2
2017
January		9.8		4.7		—
February		9.5		4.9		—
March		9.4		5.4		—
April		8.7		5.8		—
May		8.1		6.2		—
June		6.7		6.3		—
July		5.9		6.4		—
August		5.6		6.7		—
September		4.5		6.3		—
October		5.3		6.4		—
November		5.2		6.6		—
December(6)		—		—		10.4

(1) For annual figures, changes in price indices are calculated each December.

(2) National Producer Price Index figures represent the changes in the prices for basic merchandise and services (excluding oil prices). The index is based on a methodology implemented in June 2012.

(3) Preliminary figures for 2016-2017.

(4) National Producer Price Index takes June 2012 as a base date.

(5) National Consumer Price Index takes the second half of December 2010 as a base date.

(6) December 2017 National Producer Price Index and National Consumer Price Index figures not available.

Sources: INEGI; Ministry of Labor.

During the first nine months of 2017, interest rates on 28-day Cetes averaged 6.6%, as compared to 3.8% during the same period of 2016. Interest rates on 91-day Cetes averaged 6.8%, as compared to 4.0% during the same period of 2016.

On December 28, 2017, the 28-day Cetes rate was 7.22% and the 91-day Cetes rate was 7.36%.

Exchange Controls and Foreign Exchange Rates

On December 29, 2017, the peso/dollar exchange rate closed at Ps. 19.6629 = U.S. $1.00, a 4.6% appreciation in dollar terms as compared to the rate on December 31, 2016. The peso/U.S. dollar exchange rate announced by Banco de México on December 29, 2017 (which took effect on the second business day thereafter) was Ps. 19.6595 = U.S. $1.00.

Securities Markets

The BMV is the only authorized stock exchange involved in the listing and trading of equity and debt securities in Mexico. Upon the consummation of the initial public offering of its shares on June 18, 2008, the BMV was transformed from a sociedad anónima de capital variable (private company) to a sociedad anónima

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bursátil de capital variable (public company). In connection with the initial public offering of shares, certain of the former stockholders of the BMV (banks and brokerage houses) created a control trust into which they deposited more than 50% of the issued and outstanding shares of the BMV, for purposes of voting such shares in the future as a single block. Both debt and equity securities are listed and traded on the BMV, including stocks and bonds of private sector corporations, equity certificates or shares issued by banks, commercial paper, bankers’ acceptances, certificates of deposit, Mexican Government debt and special hedging instruments linked to the dollar. Currently, institutional investors are the most active participants in the BMV, although retail investors also play a role in the market. The Mexican equity market is one of Latin America’s largest in terms of market capitalization, but it remains relatively small and illiquid compared to major world markets.

The BMV publishes the Índice de Precios y Cotizaciones (Stock Market Index, or IPC) based on a group of the thirty-five most actively traded shares.

On December 28, 2017, the IPC stood at 48,862 points, representing a 7.1% increase from the level at December 30, 2016.

Foreign Trade and Balance of Payments

Foreign Trade

The following table provides information about the value of Mexico’s merchandise exports and imports (excluding tourism) for the periods indicated.

Exports and Imports

	2012		2013			2014			2015			2016(1)			First nine months of 2017(1)
	(in millions of dollars, except average price of the Mexican crude oil mix)
Merchandise exports (f.o.b.)
Oil and oil products	$	52,956	$	49,481		$	42,369		$	23,100		$	18,818		$	16,248.5
Crude oil		46,852		42,712			35,638			18,451			15,575			13,349.0
Other		6,103		6,770			6,731			4,648			3,243			2,899.5
Non-oil products		317,814		330,534			354,542			357,450			355,122			283,039.7
Agricultural		10,914		11,246			12,181			12,971			14,672			11,685.5
Mining		4,906		4,714			5,064			4,505			4,368			3,988.9
Manufactured goods(2)		301,993		314,573			337,297			339,975			336,081			267,365.3
Total merchandise exports		370,770		380,015			396,912			380,550			373,939			299,288.2
Merchandise imports (f.o.b.)
Consumer goods		54,272		57,329			58,299			56,279			51,950			41,064.3
Intermediate goods(2)		277,911		284,823			302,031			297,253			294,994			237,122.8
Capital goods		38,568		39,057			39,647			41,700			40,120			30,152.3
Total merchandise imports		370,752		381,210			399,977			395,232			387,064			308,339.4
Trade balance	$	18	$	(1,195	)	$	(3,066	)	$	(14,683	)	$	(13,125	)	$	(9,051.2	)
Average price of Mexican oil mix(3)	$	102.0	$	98.4		$	85.5		$	43.1		$	35.6		$	44.3

Note: Numbers may not total due to rounding.

(1) Preliminary figures.

(2) Includes the in-bond industry.

(3) In U.S. dollars per barrel.

Source: Banco de México / PEMEX.

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During the first nine months of 2017, total merchandise exports increased by 9.3% as compared to the same period of 2016, while total merchandise imports increased by 7.8%. The trade balance for the first nine months of 2017 registered a deficit of U.S. $9.1 billion as compared to the U.S. $12.3 billion deficit registered in the same period in 2016. This deficit was a result of the combination of an increase in both merchandise exports and merchandise imports.

Balance of Payments and International Reserves

During the third quarter of 2017, Mexico’s current account registered a deficit of U.S. $5,528 million. The increase in the oil deficit was offset by a decrease in the non-oil trade balance deficit, caused by a strengthening of global economic activity which contributed to the recovery of Mexican manufactured exports, an increase in the Primary Income balance, as well as an increase in the surplus of the remittances account. The capital account registered a deficit of U.S.$4 million in the third quarter of 2017, while the financial account registered outflows of U.S. $9.2 billion, which was due to a net outflow of foreign direct investment and portfolio investment, offset by other investment.

During 2017, the Mexican Government removed price controls on gasoline and diesel and, as of December 31, 2017, gasoline and diesel prices are determined by the free market . Mexico cannot predict the effect of changes in gasoline and diesel prices, and any related political and social unrest, on the Mexican economy or whether the Mexican Government may alter its strategy with respect to fuel prices in the future.

The following table sets forth Banco de México’s international reserves and net international assets at the end of each period indicated.

International Reserves and Net International Assets⁽³⁾

Year	End-of-Period International Reserves(1)(2)		End-of-Period Net International Assets
	(in millions of dollars)
2012	$	163,515	$	167,082
2013		176,522		180,232
2014		193,239		195,714
2015		176,735		177,629
2016		176,542		178,057
2017(4)
January		174,791		176,657
February		175,145		181,847
March		174,931		178,735
April		175,011		176,779
May		175,138		177,045
June		174,246		175,425
July		173,360		175,713
August		173,032		174,482
September		173,031		174,920
October		172,820		177,208
November		172,672		174,474
December(5)		172,465		175,253

(1) Includes gold, Special Drawing Rights (international reserve assets created by the IMF) and foreign exchange holdings.

(2) “International reserves” are equivalent to: (a) gross international reserves, minus (b) international liabilities of Banco de México with maturities of less than six months.

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(3) “Net international assets” are defined as: (a) gross international reserves, plus (b) assets with maturities greater than six months derived from credit agreements with central banks, less (x) liabilities outstanding to the IMF and (y) liabilities with maturities of less than six months derived from credit agreements with central banks.

(4) Preliminary figures.

(5) Figures as of December 22, 2017.

Source: Banco de México.

Public Finance

Fiscal Policy

The Programa Nacional de Financiamiento del Desarrollo 2013-2018 (National Program to Finance Development 2013-2018, or PRONAFIDE), which was approved and published in the Official Gazette of the Federation on May 20, 2013 and announced on December 16, 2013, establishes the Mexican Government’s fiscal policy goals. These goals include securing sufficient fiscal resources to strengthen social infrastructure and productivity. To this end, PRONAFIDE has outlined several specific objectives, including the promotion of economic development and macroeconomic stability on a federal and state level, as well as the improvement of the financial system to generate additional resources and to transform the financial system into a simpler, more progressive and more transparent system through spending efficiency and the facilitation of access to financial services.

2017 UMS Budget and Fiscal Results

On September 8, 2016, the President of Mexico submitted the proposed 2017 Federal Revenue Law and the proposed 2017 Federal Expenditure Budget to Congress for its approval. The 2017 Revenue Law was approved by the Senate on October 26, 2016, and the 2017 Expenditure Budget was approved by the Chamber of Deputies on November 11, 2016. They were published in the Official Gazette of the Federation on November 15, 2016 and November 30, 2016, respectively. We refer to these two bills together as Mexico’s 2017 budget (the 2017 UMS Budget).

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The following table illustrates the composition of public sector budgetary revenues for the first nine months of 2016 and 2017.

2017 Public Sector Budgetary Revenues

	First nine months of 2016(1)		First nine months of 2017(1)		2017 Budget(2)		2018 Budget(2)
	(in billions of constant pesos)(3)
Budgetary revenues		3,501.2		3,773.0		4,360.9		4,778.3
Federal government		2,655.4		2,986.3		3,263.8		3,584.9
Taxes		2,041.5		2,182.7		2,739.4		2,957.5
Income tax		1,066.0		1,188.7		1,422.7		1,564.3
Value-added tax		586.0		637.6		797.7		876.9
Excise taxes		322.5		282.4		433.9		421.8
Import duties		37.2		38.5		45.8		47.3
Export duties		0.0		0.0		0.0		0.0
Luxury goods and services		0.0		0.0		0.0		0.0
Other		26.9		32.3		39.3		42.4
Non-tax revenue		613.9		809.2		524.4		627.4
Fees and tolls		46.1		51.9		50.7		46.4
Transfers from the Mexican Petroleum Fund for Stabilization and Development		238.3		335.3		386.9		456.8
Rents, interest and proceeds of assets sales		0.0		0.0		0.0		0.0
Fines and surcharges		322.8		416.4		86.7		117.8
Other		6.6		5.6		0.0		6.5
Public enterprises and agencies		845.8		786.7		1,097.2		1,193.3
PEMEX		382.6		255.1		400.4		423.3
Others		463.2		531.6		696.7		770.0

Note: Numbers may not total due to rounding.

(1) Preliminary figures.

(2) Budgetary estimates as of December 2016. Budgetary estimates for 2017 were converted into constant pesos using the GDP deflator for 2017, estimated as of December 2016.

(3) Constant pesos with purchasing power as of December 31, 2013.

Source: Ministry of Finance and Public Credit.

2018 UMS Budget

On September 8, 2017, the President of Mexico submitted the proposed Ley de Ingresos de la Federación para el Ejercicio Fiscal de 2018 (Federal Revenue Law for 2018, or the 2018 Revenue Law) and the proposed Presupuesto de Egresos de la Federación para el Ejercicio Fiscal de 2018 (Federal Expenditure Budget for 2018, the 2018 Expenditure Budget to the Mexican Congress for its approval. The 2018 Revenue Law was approved by the Cámara de Diputados (Chamber of Deputies) on October 19, 2017 and by the Senate on October 27, 2017. The 2018 Revenue Law was published in the Official Gazette of the Federation on November 15, 2017. The 2018 Expenditure Budget was approved by the Chamber of Deputies on November 9, 2017 and was published in the Official Gazette of the Federation on November 29, 2017. We refer to these two bills together as Mexico’s 2018 budget (the 2018 UMS Budget).

Public Debt

External Public Debt

Mexico’s external public debt goals are intended to provide the Mexican Government with flexibility to finance its stated needs, while also accounting for market volatility and unforeseen developments. The policy also seeks to maintain

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costs and risks at stable levels. Mexico primarily seeks debt financing through local markets, supplemented by external financing from the U.S., Europe and Japan. Mexico’s principal objectives in connection with its external financing include improving the terms and conditions of Mexico’s external liabilities, as well as strengthening and diversifying Mexico’s investor base, with specific consideration to Mexico’s continued presence in the most influential international markets. Objectives also include strengthening Mexico’s benchmark bonds and maintaining a constant relationship with international investors in order to ensure transparency and to promote investment in Mexico.

Internal Public Debt

The Mexican Government’s “net internal debt” includes only the internal portion of indebtedness incurred directly by the Mexican Government and the assets of the Fondo del Sistema de Ahorro Para el Retiro (Retirement Savings System Fund). In addition, “net internal debt” is comprised of Cetes and other securities sold to the public in auctions for new issuances (primary auctions) but does not include any debt allocated to Banco de México for its use in Regulación Monetaria (regulating the money supply). It also does not include debt by the Instituto para la Protección al Ahorro Bancario (Bank Savings Protection Institute, or IPAB) or the debt of budget-controlled or administratively-controlled agencies. At December 31, 2016, all of the Mexican Government’s internal debt was denominated in pesos or UDIs and was payable in pesos.

Over the last two decades, the Mexican Government has actively sought to increase its average debt maturity date. Accordingly, the Mexican Government has issued new debt instruments bearing longer maturities than those previously issued. In doing so, the Mexican Government hopes to mitigate any risk associated with the refinancing of its internal public debt. This has had the effect of establishing a long-dated benchmark yield curve (the line that plots interest rates across different contract lengths for bonds having equal credit quality). These issuances have also encouraged long-term investments in the following areas: (1) fixed-rate contracts; (2) peso-denominated securities by Mexican companies; (3) Mexican financial hedging products; and (4) the use of long-term savings in financing long-term investment projects.

As a result of this policy, the average maturity of the Government’s internal debt increased from 7.6 years at December 31, 2011 to 8.0 years at December 31, 2016.

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The following table summarizes the gross and net internal debt of the Mexican Government at each of the dates indicated.

Gross and Net Internal Debt of the Mexican Government⁽¹⁾

	At December 31,																									At September 30,
	2012					2013					2014					2015					2016					2017(2)
	(in billions of pesos, except percentages)
Gross Debt
Government Securities		Ps. 3,257.8		91.1	%		Ps. 3,734.1		91.9	%		Ps. 4,223.3		92.9	%		Ps. 4,701.2		92.7	%		Ps. 4,915.3		87.5	%		Ps. 5,407.3		90	%
Cetes		531.3		14.9			635.6		15.6			678.7		14.9			655.8		12.9			634.7		11.3			678.9		11
Floating Rate Bonds		200.4		5.6			216.6		5.3			232.6		5.1			296.5		5.8			397.9		7.1			460.8		8
Inflation-Linked Bonds		747.2		20.9			888.7		21.9			1,011.1		22.2			1,196.6		23.6			1,223.5		21.8			1,434.6		24
Fixed Rate Bonds		1,777.9		49.7			1,989.6		49.0			2,295.8		50.5			2,546.2		50.2			2,652.1		47.2			2,825.5		47
STRIPS of Udibonos		1.0		0.0			3.6		0.1			5.1		0.1			6.1		0.1			7.2		0.1			7.5		0
Other(3)		317.6		8.9			329.1		8.1			323.3		7.1			372.8		7.3			705.0		12.5			591.5		10
Total Gross Debt		Ps. 3,575.3		100.0	%		Ps. 4,063.2		100.0	%		Ps. 4,546.6		100.0	%		Ps. 5,074.0		100.0	%		5,620.3		100.0	%		Ps. 5,998.8		100.0	%
Net Debt
Financial Assets(4)		(74.2	)				(169.3	)				(222.5	)				(259.9	)				(224.0	)				594.7
Total Net Debt		Ps. 3,501.1					Ps. 3,893.9					Ps. 4,324.1					Ps. 4,814.1					Ps. 5,396.3					Ps. 5,404.1
Gross Internal Debt/GDP		22.1	%				24.2	%				25.3	%				26.9	%				27.8	%				28.2	%
Net Internal Debt/GDP		21.6	%				23.2	%				24.0	%				25.5	%				26.7	%				25.4	%

Note: Numbers may not total due to rounding.

(1) Internal debt figures do not include securities sold by Banco de México in open-market operations to manage liquidity levels pursuant to Regulación Monetaria. This is because the securities do not increase the Mexican Government’s overall level of internal debt. Banco de México must reimburse the Mexican Government for any allocated debt that Banco de México sells into the secondary market and that is presented to the Mexican Government for payment. If Banco de México undertakes extensive sales of allocated debt in the secondary market, however, this can result in an elevated level of outstanding internal debt as compared to the Mexican Government’s figure for net internal debt.

(2) Preliminary figures.

(3) Includes Ps. 169.0 billion for 2012, Ps. 165.5 billion for 2013, Ps. 161.5 billion for 2014, Ps. 153.8 billion for 2015, Ps. 147.5 billion for December 31, 2016 and Ps. 142.7 billion at September 30, 2017 in liabilities associated with social security under the ISSSTE Law.

(4) Includes the net balance (denominated in pesos) of the Federal Treasury’s General Account in Banco de México.

Source: Ministry of Finance and Public Credit

External Public Debt

“External public sector debt” consists of the external portion of the long-term indebtedness incurred directly by the Mexican Government, the external long-term indebtedness incurred by budget-controlled agencies, the external long-term indebtedness incurred directly by productive state-owned companies, the external long-term indebtedness incurred directly or guaranteed by administratively-controlled agencies (including but not limited to national development banks) and the short-term external debt of the public sector. Private sector debt guaranteed by the Mexican Government is not included, unless and until the Mexican Government is called upon to make payment under the applicable guaranty. “External public debt” does not include, among other things, repurchase obligations of Banco de México with the IMF.

According to preliminary figures, at September 30, 2017, outstanding gross public sector external debt totaled U.S. $193.7 billion, an approximate U.S. $12.7 billion increase from the U.S. $181.0 billion outstanding at December 31, 2016. Of this amount, U.S. $191.3 billion represented long-term debt and U.S. $2.5 billion represented short-term debt. Net external indebtedness also increased by U.S. $14.1 billion during the first nine months of 2017, mainly due to an increase in indebtedness issued on the capital markets. Overall, at December 31, 2016, total public debt (gross external debt plus net internal public sector debt) represented approximately 48.2% of nominal GDP, an increase of 5.4 percentage points from December 31, 2015.

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The following tables set forth a summary of Mexico’s external public debt, including a breakdown of such debt by currency, net external public sector debt, the Mexican Government’s gross external debt, the Mexican Government’s net external debt and the Mexican Government’s net debt.

Summary of External Public Debt

By Type ⁽¹⁾

	Long-Term Direct Debt of the Mexican Government		Long-Term Debt of Budget- Controlled Agencies		Other Long-Term Public Debt(2)		Total Long- Term Debt		Total Short- Term Debt		Total Long- and Short- Term Debt
	(in millions of U.S. dollars)
At December 31,
2012		66,912		50,063		5,626		122,601		3,125		125,726
2013		71,817		53,358		5,734		130,909		3,527		134,436
2014		78,379		58,863		5,627		142,869		4,797		147,666
2015		82,493		69,621		6,943		159,057		3,152		162,209
2016		88,083		82,688		7,122		177,893		3,093		180,986
At September 30,
2017(3)		90,635		92,895		7,731		191,261		2,463		193,724

By Currency⁽⁴⁾

	At December 31,																				At September 30,
	2012				2013				2014				2015				2016				2017(3)
	(in millions of U.S. dollars, except for percentages)
U.S. Dollars	U.S.$	105,836	84.2	%	U.S.$	111,647	83.0	%	U.S.$	121,927	82.6	%	U.S.$	131,702	81.2	%	U.S.$	144,185	79.7	%	U.S.$	149,496	77.2	%
Japanese Yen		6,847	5.4			5,519	4.1			5,058	3.4			4,857	3.0			6,410	3.5			6,690	3.5
Swiss Francs		961	0.8			969	0.7			401	0.3			1,011	0.6			1,331	0.7			1,375	0.7
Pounds Sterling		1,993	1.6			1,369	1.0			2,848	1.9			2,694	1.7			2,257	1.3			2,450	1.3
Euro		9,530	7.6			11,489	8.5			13,986	9.5			18,834	11.6			24,409	13.5			31,085	16.0
Others		558	0.4			3,443	2.6			3,445	2.3			3,113	1.9			2,393	1.3			2,629	1.4
Total	U.S.$	125,726	100.0	%	U.S.$	134,436	100.0	%	U.S.$	147,666	100.0	%	U.S.$	162,209	100.0	%	U.S.$	180,986	100.0	%	U.S.$	193,724	100.0	%

Net External Debt of the Public Sector

	At December 31,															At September 30,
	2012			2013			2014			2015			2016			2017(3)
	(in millions of U.S. dollars, except for percentages)
Total Net Debt	U.S.$	121,659.0		U.S.$	130,949.7		U.S.$	145,617.4		U.S.$	161,609.5		U.S.$	177,692.5		U.S.$	191,825.3
Gross External Debt/GDP		10.1	%		10.5	%		12.0	%		15.3	%		19.2	%		16.5	%
Net External Debt/GDP		9.8	%		10.2	%		11.9	%		15.2	%		18.8	%		16.3	%

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Gross External Debt of the Mexican Government

	At December 31,																				At September 30,
	2012				2013				2014				2015				2016				2017(3)
	(in millions of U.S. dollars, except for percentages)
U.S. Dollars	U.S.$	57,465	85.2	%	U.S.$	62,285	86.3	%	U.S.$	65,127	82.9	%	U.S.$	66,298	80.3	%	U.S.$	67,533	76.6	%	U.S.$	68,082	75.1	%
Japanese Yen		4,433	6.6			3,643	5.0			3,686	4.7			3,672	4.4			4,525	5.1			4,687	5.2
Swiss Francs		—	—			—	—			—	—			—	—			—	—			—	—
Pounds Sterling		774	1.1			789	1.1			2,302	2.9			2,177	2.6			1,825	2.1			1,981	2.2
Euros		4,771	7.1			5,447	7.6			7,437	9.5			10,422	12.6			14,256	16.2			15,868	17.5
Others		18	0.0			16	0.0			20	0.0			19	0.0			18	0.0			18	0.0
Total	U.S.$	67,461	100.0	%	U.S.$	72,180	100.0	%	U.S.$	78,573	100.0	%	U.S.$	82,588	100.0	%	U.S.$	88,157	100.0	%	U.S.$	90,635	100.0	%

Net External Debt of the Mexican Government

	At December 31,															At September 30,
	2012			2013			2014			2015			2016			2017
	(in millions of U.S. dollars, except for percentages)
Total Net Debt	U.S.$	66,016.5		U.S.$	69,910.4		U.S.$	77,352.4		U.S.$	82,320.3		U.S.$	86,666.0		U.S.$	90,326.0
Gross External Debt/GDP		5.4	%		5.6	%		6.5	%		7.8	%		9.4	%		7.7	%
Net External Debt/GDP		5.3	%		5.5	%		6.4	%		7.8	%		9.2	%		7.7	%

Net Debt of the Mexican Government

	At December 31,															At September 30,
	2012			2013			2014			2015			2016			2017
External Debt		19.7	%		19.0	%		20.8	%		22.7	%		25.0	%		76.7	%
Internal Debt		80.3	%		81.0	%		79.2	%		77.3	%		75.0	%		23.3	%

Note: Numbers may not total due to rounding.

(1) External debt denominated in foreign currencies other than U.S. dollars has been translated into dollars at exchange rates as of each of the dates indicated. External public debt does not include (a) repurchase obligations of Banco de México with the IMF (none of which were outstanding as of September 30, 2017) or (b) loans from the Commodity Credit Corporation to public sector Mexican banks. External debt is presented herein on a “gross” basis, and includes external obligations of the public sector at their full outstanding face or principal amount. For certain informational and statistical purposes, Mexico sometimes reports its external public sector debt on a “net” basis, which is calculated as the gross debt net of certain financial assets held abroad. These financial assets include Mexican public sector external debt that is held by public sector entities but that has not been cancelled. Banco de México’s reserves are not subtracted from gross debt.

(2) Includes development banks’ debt and the debt of other administratively-controlled agencies whose finances are consolidated with those of the Mexican Government.

(3) Preliminary figures.

(4) Adjusted to reflect the effect of currency swaps.

Source: Ministry of Finance and Public Credit.

Recent Securities Offerings

Mexico offers additional debt securities from time to time, and in order to manage the composition of its outstanding liabilities, Mexico engages from time to time in a variety of transactions including tender offers, open market purchases and early redemptions.

On March 28, 2017, Mexico issued U.S. $3.2 billion of its 4.150% Global Notes due 2027. Mexico used a portion of the proceeds from this offering to redeem its outstanding 5.950% Global Notes due 2019.

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On October 10, 2017, Mexico issued U.S.$1,880,000,000 4.600% Global Notes due 2048. Mexico used a portion of the proceeds from this offering to redeem its outstanding 5.125% Global Notes due 2020.

As of September 29, of 2017, Mexico had repurchased approximately U.S. $500 million in aggregate principal amount of outstanding debt securities in open market transactions.

Legal and Political Reforms

Anti-Corruption

On July 18, 2016, the Sistema Nacional Anticorrupción (National Anti-Corruption System or NAS) went into force. The NAS is an institutional framework that seeks to combat corruption and bribery in public administration and governmental accounting.

On December 21, 2016, the U.S. Department of Justice publicly disclosed that Odebrecht S.A. (or Odebrecht), a global construction conglomerate based in Brazil, pled guilty to charges of bribery and corruption in connection with, among other things, bribes paid for more than 100 projects in twelve countries. On December 22, 2016, authorities commenced administrative and criminal investigations into instances of bribery or corruption related to these allegations. On January 25, 2017, the Mexican Government filed a criminal complaint with the Federal Attorney General’s Office against any party for acts that may have been committed against it.

Access to Information and Government Transparency

On May 9, 2016 the Ley Federal de Transparencia y Acceso a la Información Pública (Federal Law for Transparency and Access to Public Information) was published in the Official Gazette of the Federation, abrogating the former law of the same name. This law continues to ensure the right to access to information held by governmental entities and, additionally, was expanded to include transparency obligations for the armed forces, the Agencia Nacional de Seguridad Industrial y de Protección al Medio Ambiente del Sector Hidrocarburos (National Agency for Industrial Safety and Environmental Protection on Hydrocarbons Sector), the CNH, the CRE, the Fondo Mexicano del Petróleo para la Estabilización y el Desarrollo (Mexican Petroleum Fund for Stabilization and Development) and the productive state-owned companies. The new law sets forth the authority of the Instituto Nacional de Transparencia, Acceso a la Información y Protección de Datos Personales (National Institute of Transparency, Information Access and Protection of Private Data or INAI) to impose sanctions.

Criminal Justice

In June 2008, the Constitución Política de los Estados Unidos Mexicanos (the Political Constitution of Mexico, or the Constitution) was amended to reform the criminal justice system. The reforms were implemented over a period of eight years and went into force on June 18, 2016. Under the reforms, Mexico transitioned to an accusatory system of criminal justice, in which defendants are presumed innocent until proven guilty. Closed-door proceedings, previously conducted almost exclusively through written briefs, will be replaced with oral trials open to the public. A specific judge will be named to each criminal proceeding and will follow that proceeding through the sentencing phase and will be required to be present at every hearing. The victims of criminal activity are more directly involved in criminal proceedings and benefit from increased protection of their personal data, as well as access to legal, medical and psychological assistance.

Local Government Finance

On April 27, 2016, the Ley de Disciplina Financiera de las Entidades Federativas y los Municipios (Law for the Financial Discipline of the States and the Municipalities) was published in the Official Gazette of the

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Federation. Pursuant to the law, states and municipalities will need the authorization of the local congress to incur additional indebtedness if their outstanding indebtedness is higher than six percent of the revenues approved by the Legislative branch for the applicable fiscal year. The law also imposes a new set of requirements that must be met prior to having the Mexican Government guarantee debt issued by states and municipalities. This legislation follows a May 2015 decree amending various provisions of the Constitution, creating a new legal framework to control the borrowing practices of the states and municipalities.

Economic Development

On June 1, 2016, the Ley de Zonas Económicas Especiales (Law of Special Economic Zones) was published in the Official Gazette of the Federation. This law is part of the National Development Plan and its purpose is to regulate the establishment and operation of the Special Economic Zones and promote sustainable economic growth in the undeveloped regions of the country, particularly the southern region of Mexico. The Special Economic Zones are designated geographic areas subject to special incentives to promote business, attract new investment and generate employment opportunities through infrastructure development projects.

Consistent with the National Development Plan, on January 9, 2017, the Mexican Government announced that it signed the Acuerdo para el Fortalecimiento Económico y la Protección de la Economía Familiar (Agreement for Economic Strengthening and Protection of the Economy of the Family). This agreement aims to strengthen the domestic market in Mexico with a focus on protecting the economic well-being of Mexican families, increasing investment and maintaining job creation, economic growth and competitiveness.

On May 15, 2017, the Disposiciones de Carácter General Aplicables a las Bolsas de Valores (General Provisions Applicable to Stock Exchanges) were published in the Official Gazette of the Federation. These General Provisions strengthen the regulatory framework applicable to stock exchanges, including, among other measures, enhanced internal controls of the stock market, rules covering the disclosure of market-moving information and the establishment of contingency plans for stock exchanges experiencing operational distress.

On August 29, 2017, the concession for a new stock exchange in Mexico was published in the Official Gazette of the Federation by the Ministry of Finance and Public Credit. The new Bolsa Institutional de Valores (Institutional Stock Exchange, or BIVA) will begin operations once it fulfills the requirements set forth in the Ley del Mercado de Valores (Stock Market Exchange Law). This new concession was granted as part of the Ministry of Finance and Public Credit’s program to develop the securities market based on four main pillars: (1) changing the configuration and regulation of securities; (2) providing for the participation of development banks to promote securities markets; (3) changing the regulation of retirement funds and insurance companies to encourage investment in new projects and creating reference portfolios to establish incentives to participate in the securities market; and (4) developing a national strategy for financial education to encourage participation in development instruments.

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Item 4A. Unresolved Staff Comments

Not applicable.

Item 5. Operating and Financial Review and Prospects

General

We earn income from:

• export sales, which consist of sales of crude oil and condensates, petroleum products and petrochemical products;

• domestic sales, which consist of sales of natural gas, petroleum products (such as gasoline, diesel fuel and LPG) and petrochemical products; and

• other sources, including financial and investment income and insurance revenue.

Our operating expenses include:

• cost of sales, including the cost of purchases of imported petroleum and other products, depreciation and amortization, salaries, wages and benefits, a portion of the net cost of employee benefits for the period, the variation of inventories, maintenance, and exploration and unsuccessful drilling expenses;

• transportation and distribution expenses (including a portion of the net cost of employee benefits for the period); and

• administrative expenses (including a portion of the net cost of employee benefits for the period).

Our income is affected by a number of factors, including:

• changes in international prices of crude oil, petroleum products and petrochemical products, which are denominated in U.S. dollars, and domestic prices of petroleum products, which are denominated in pesos;

• the type and volume of crude oil produced and exported;

• the type and volume of natural gas produced, processed and sold domestically and internationally;

• the results of development and exploration activities;

• the amount of taxes, duties and other payments that we are required to make to the Mexican Government;

• fluctuations in the peso-U.S. dollar exchange rate; and

• Mexican and global economic conditions, including the levels of international interest rates.

Overview

In 2017 we focused on further recovering our financial stability, taking concrete steps towards implementing and building on the opportunities presented to us by the energy reform and strengthening the relationship with our stakeholders, including with our more recent partners in farm-outs and other associations. These actions took place against a macroeconomic landscape that continues to be challenging for us. While the decline in crude oil prices that commenced in late 2014 began to stabilize in 2017 and prices even began to rise slowly, we remain in a low price environment. In 2017, the weighted average price of the Mexican crude oil export price increased from U.S. $35.63 per barrel in 2016 to U.S. $46.73 per barrel.

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Going Concern

Our consolidated financial statements as of December 31, 2017 and 2016 have been prepared on a going concern basis, which assumes that we can meet our payment obligations. As we describe in Note 2 to our consolidated financial statements, we have experienced certain conditions that have generated material uncertainty that may cast significant doubt on our ability to continue operating as a going concern. We discuss below, and in Note 2 to our consolidated financial statements, the circumstances that have caused these negative trends and the concrete actions we are taking to improve our results, strengthen our ability to continue operating, and achieve revenue maximization and efficiencies in an economic environment which is showing recovery and some stability. We continue operating as a going concern, and our consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.

Redefinition of Petróleos Mexicanos as a State-Owned Productive Company

We are continuing to implement a business strategy that redefines us as a state-owned productive company, enables us to operate competitively and efficiently and takes advantage of the opportunities made available to us by the energy reform. As a productive state-owned company, our business model contemplates maximizing value for Mexico and, accordingly, we intend to focus on high-yield projects with growth potential. Every action taken under our business plan will be directed towards the efficient allocation of resources, developing profitable businesses and considering the development of new businesses with third parties. These opportunities include expanding the scope of activities in which we participate, enhancing our ability to acquire technology and knowledge along the entire hydrocarbons value chain through strategic alliances and continuing the migration of certain assignments into exploration and production contracts.

Commencing in 2016, we have begun to take certain actions to increase our efficiency and competitiveness. Towards that end, we have continued with our implementation of the 2017-2021 Business Plan (described below), and have otherwise taken advantage of the opportunities provided by the energy reform in the following ways:

• 2017-2021 Business Plan: On November 3, 2016, we announced our business plan for the five-year period from 2017 through 2021 (which we refer to as the 2017-2021 Business Plan), which is designed to improve cash flows, reduce net indebtedness, strengthen our financial balance (which we define as sales after deducting costs and expenses, investment expenses, taxes and duties, and financial debt service), reduce financial losses in our National Refining System and plans for continued cost-cutting and administrative discipline, as well as the establishment of additional alliances, including an intensive farm-out program. We intend to continue to execute on our business plan in 2018, even while our management seeks to update it with a 2018 plan that is currently under evaluation.

• Farm-outs and Other Associations: An important part of our business plan is the leveraging of resources and expertise of third parties. In 2017, we entered into our first farm-out in deep waters (Trión) and our first two onshore farm-outs (Cárdenas-Mora and Ogarrio) and we intend to continue our farm-out program in 2018. We expect that these farm-outs will allow us to recoup some of our previous investments in our fields, as well as share certain risks associated with further development of those fields, while maintaining an interest in future profits. In addition, we participated and won assignments in multiple bidding rounds in 2017 and we intend to participate in subsequent bidding rounds, either with partners or independently, in order to further diversify and strengthen our exploration and production portfolio.

• Improved Financial Position: In addition to taking advantage of new business opportunities and arrangements provided by the energy reform, such as farm-outs, we also continue to take certain specific measures to improve our financial position, including the following:

• Pension Reform: As of January 1, 2016, new employees receive a defined contribution plan, pursuant to which both we and our employees contribute to each employee’s individual account,

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in contrast to the defined benefit pension plan, pursuant to which only we contribute. To further reduce our pension liabilities, we are inviting employees hired prior to 2016 to transfer from their existing defined benefit pension plan to a defined contribution plan. We expect that this will allow us to decrease our employee benefits service cost and employee benefits liability going forward.

• Assets Sales: In November 2017, we completed the divestiture of Ductos y Energéticos del Norte, S. de R.L. de C.V. and we continue to evaluate the divestiture of other non-essential assets to obtain working capital, such as the divestiture of TAG Norte Holding, S. de R.L. C.V., which we expect will be concluded in the first half of 2018.

• Decreased Debt Financing: We also intend to improve our financial position by relying less on debt financing. As part of that strategy, in 2017 we issued Ps. 72.4 billion in debt, which is significantly less than the Ps. 231.6 billion we issued in 2016. For the year 2018, we intend to continue this strategy and are authorized to incur additional internal net debt of Ps. 30 billion and an additional external net debt of U.S. $6.2 billion. We continue to evaluate market conditions for opportunities to execute liability management transactions, which we expect will allow us to improve the terms of our outstanding debt.

• 2018 Plans: Our 2018 plans set out certain objectives we expect to achieve with respect to our subsidiary entities as follows:

• Pemex Exploration and Production. Pemex Exploration and Production will focus on maintaining production levels and developing farm-outs and associations with the aim of increasing its operations and, with time, the production of hydrocarbons in the mid-term. Pemex Exploration and Production will also accelerate the migration of Integrated E&P Contracts and FPWC to exploration and extraction contracts and will focus on the rehabilitation and reincorporation activities of wells with production possibilities. In 2018, Pemex Exploration and Production will continue to promote actions that encourage efficiency and optimize costs.

In order to continue to take advantage of the benefits of the energy reform and to ensure our economic sustainability, in 2018 and in the up-coming years, Pemex Exploration and Production will focus on the following strategies: (1) establishment of an exploration model that allows us to grow our proven, probably and possible reserves; (2) further development of business plans for the development of shale; (3) containment and reversal of production decline and increase of profitability of assignments migrated without third party participation; (4) entering into and developing existing strategic alliances, partnertships and other arrangements to attract additional investment and to expand exploration activities; (5) focus on maintenance to improve the safety of our operations; (6) improved operational efficiency and cost control; and (7) an increase in sales of our hydrocarbons.

• Pemex Industrial Transformation. With respect to Pemex Industrial Transformation, we will continue to perform reconfiguration and auxiliary services for our refineries and we will focus on the following strategies in 2018: (1) keeping our facilities safe and reliable, (2) improving the financial balance, (3) maintaining a significant market share in Mexico and (4) eliminating debts, which will help to improve our refining margin.

• Pemex Logistics. After holding its first successful Open Season Public Auction in 2017, Pemex Logistics will continue to evaluate opportunities for executing subsequent auctions for certain of its pipelines and storage systems with the goal of diversifying its customer base and improving profitability.

• Pemex Fertilizers, Pemex Ethylene and Pemex Drilling and Services. With respect to Pemex Fertilizers, Pemex Ethylene and Pemex Drilling and Services, we continue to focus on efficiency and profitability by, among others, entering into service contracts and by seeking partnerships for the purpose of modernizing our facilities.

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• New Budget: On July 14, 2017, Petróleos Mexicanos’ Board of Directors approved a proposal for the consolidated annual budget of Petróleos Mexicanos and the subsidiary entities for 2018, which was subsequently approved by the Mexican Congress on November 9, 2017 and published in the Official Gazette of the Federation on November 15, 2017. The consolidated annual budget of Petróleos Mexicanos and the subsidiary entities for 2018 approved by the Mexican Chamber of Deputies is approximately Ps. 391.9 billion, as compared to the Ps. 385.2 billion consolidated annual budget for 2017.

In addition, while we remain in a low price environment, if prices and markets for hydrocarbons continue to stabilize, this may allow us to accelerate the development of our fields, through partnerships or alone, contain the decline in our production and increase our revenues through the initiatives described above. In July 2018, presidential and federal congressional elections will be held in Mexico, which could also have an impact on the political and economic environment of the oil and gas industry and, in turn, our strategy.

Results of operations and financial condition in 2017

For the year ended December 31, 2017, we increased our net loss by 47.0%, from a net loss of Ps. 191.1 billion (U.S. $9.3 billion) in 2016 to a net loss of Ps. 280.9 billion (U.S. $14.2 billion) in 2017. This increase in net loss was primarily due to:

• a Ps. 482.8 billion increase in impairment of wells, pipelines, properties, plant and equipment;

• a Ps. 138.4 billion increase in cost of sales, mainly due to an increase in total sales;

• a Ps. 68.5 billion increase in taxes and other duties;

• a Ps. 17.5 billion decrease in other revenues, net;

• a Ps. 3.9 billion increase in general expenses; and

• a Ps. 1.8 billion decrease in profit sharing in joint ventures, associates and other.

This increase was partially offset by:

• a Ps. 322.9 billion increase in total sales, mainly due to an increase in the average price of crude oil and natural gas;

• a Ps. 277.2 billion decrease in exchange loss, net; and

• a Ps. 23.0 billion decrease in financing cost, net.

For more information on our results of operations, see “—Results of Operations of Petróleos Mexicanos, the Subsidiary Entities and the Subsidiary Companies—For the Year Ended December 31, 2017 Compared to the Year Ended December 31, 2016” below.

In 2017, our (deficit) equity increased by Ps. 269.3 billion from negative Ps. 1,233.0 billion as of December 31, 2016 to negative Ps. 1,502.4 billion as of December 31, 2017. For more information on our deficit increase, see “—Liquidity and Capital Resources—Equity Structure and Mexican Government Contributions” below. This increase was mainly due to (1) our net loss for the year of Ps. 280.9 billion; (2) a Ps. 12.0 billion increase in actuarial gains on employee benefits; and (3) Ps. 6.0 billion in accumulated loss from the foreign currency translation effect.

Although we continue to depend heavily on net cash flows from financing activities, in 2017 we were able to strengthen our liquidity. Our accounts receivable, net, increased 37.4% in 2017, from Ps. 133.2 billion as of December 31, 2016 to Ps. 170.6 billion as of December 31, 2017, mainly due to the following:

• an increase in accounts receivables from sales to our international customers;

• customer services reimbursements;

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• the current portion of the promissory notes issued by the Mexican Government in relation to our pension liabilities;

• higher accounts receivable from gasoline distributors; and

• an increase in tax credits associated with hydrocarbon extraction duties.

In addition to increasing our assets, during 2017 we continued to address one of the most critical problems we faced in 2015—our accounts payable to suppliers. As of December 31, 2017, we owed our suppliers approximately Ps. 140.0 billion as compared to Ps. 151.6 billion as of December 31, 2016. As of December 31, 2017, we have paid the total outstanding balance due to suppliers and contractors as of December 31, 2016 and, as of March 31, 2018, we have paid approximately 75.0% of the total outstanding balance due to suppliers and contractors as of December 31, 2017.

Operating Challenges

During 2017 our crude oil production totaled 1,948.3 thousand barrels per day, which, while slightly surpassing our target of 1,944 thousand barrels per day for 2017, represented a decrease of 205.2 thousand barrels per day, or 9.5%, as compared to 2016. This decline was primarily a result of the natural decline of certain of our fields. We describe the reasons for this decline under “Item 4—Information on the Company—Business Overview—Exploration and Production—Crude Oil and Natural Gas Production.” For 2018, we have set a crude oil production target of 1,951 thousand barrels per day.

In 2017, the total crude oil we processed decreased by 17.8% to 767.0 thousand barrels per day, primarily due to unscheduled shutdowns at our Salina Cruz refinery as a result of natural disasters and the implementation of general maintenance programs at our Madero and Minatitlán refineries. As a result, usage of our primary distillation capacity decreased by 11.1% to 47.1% in 2017. Although we had a decrease in crude oil processing, our variable refining margin increased by U.S. $0.95 per barrel to U.S. $5.43 per barrel in 2017, primarily as a result of the increase in average sales prices for refined products.

Critical Accounting Policies

Some of our accounting policies require the application of estimates, judgments and assumptions by management which affect the reported amounts of assets and liabilities as of the date of our financial statements, as well as the reported amounts of revenues and expenses during the periods presented in this report. By their nature, these estimates, judgments and assumptions are subject to a degree of uncertainty and are based on: our historical experience; terms of existing contracts; management’s view of trends in the oil and gas industry, both internationally and within Mexico; economic factors in Mexico; and information from outside sources. We believe that the following critical accounting policies, among others, affect management’s judgments and estimates used in the preparation of our consolidated financial statements according to IFRS, and could potentially impact our financial results and future financial performance. There can be no assurance that actual results do not differ from these estimates. These policies are more fully described in Note 3 to our consolidated financial statements included herein.

Successful Efforts Method of Oil and Gas Accounting

We apply the successful efforts method for the exploration and production of crude oil and gas activities, considering the criteria mentioned in IFRS 6, “Exploration for and Evaluation of Mineral Resources,” in relation to the recognition of exploration and drilling assets. Costs of development wells and related plant, property and equipment involved in the exploitation of oil and gas are recorded as part of the cost of assets. The costs of exploratory wells in areas that have not yet been designated as containing proved reserves are recorded as intangible assets until it is determined whether such reserves are commercially viable. Otherwise, the costs of drilling an exploratory well are charged to exploration expense. Other expenditures on exploration are charged to exploration expense, as incurred.

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Depreciation and amortization of capitalized costs associated with wells are based on the estimated commercial life of the field to which the well corresponds, taking into account the relationship between the field’s production levels for the period and proved developed reserves, as of the beginning of the year and as updated on a quarterly basis for new development investments.

Reserves estimates are determined in accordance with earth science and petroleum engineering principles and practices pursuant to Rule 4-10(a) and, where necessary, in accordance with the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the SPE as of February 19, 2007. These procedures are consistent with international reserves reporting practices. The estimation of these reserves depends on assumptions made and the interpretation of the data available, and can vary as a result of changes in such factors as forecasted oil and gas prices, reservoir performance and developments in oil field technology. The results of drilling activities, test wells and production after the date of estimation are utilized in future revisions of reserves estimates.

Downward revision of reserves estimates can result in: higher depreciation and depletion expense per barrel in future periods; an immediate write-down of an asset’s book value in accordance with accounting rules for the impairment of properties; or changes in our accrual of the asset retirement obligation. An impairment of oil and gas producing fixed assets will result if the downward revisions are so significant that the estimated future cash flows from the remaining reserves in the field are insufficient to recover the unamortized capitalized costs. Conversely, if the oil and gas reserves quantities are revised upward, our per barrel depreciation and depletion expense will be lower.

The application of successful efforts accounting can also cause material fluctuations between periods in exploration expenses if drilling results are different than expected or if we change our exploration and development plans. The determination that exploratory drilling was unsuccessful in finding economically producible reserves requires the immediate expensing of previously capitalized drilling costs. We make periodic assessments of the amounts included within intangible assets to determine whether capitalization is initially appropriate and should continue. Exploration wells capitalized beyond 12 months are subject to additional evaluation as to whether the facts and circumstances have changed, and therefore whether the conditions described below no longer apply. Exploration wells more than 12 months old are expensed unless: they are in an area requiring major capital expenditures before production can begin, commercially productive quantities of reserves have been found, and they are subject to further exploration or appraisal activity, in that either drilling of additional exploratory wells is underway or firmly planned for the near future; or proved reserves are identified within 12 months following the completion of exploratory drilling.

Environmental Remediation and Asset Retirement Obligations

We are required to make judgments and estimates in recording liabilities for environmental cleanup and asset retirement obligations. In accordance with applicable legal requirements and accounting practices, we recognize an environmental liability when the cash outflows are probable and the amount is reasonably estimable. We account for disbursements related to the conservation of the environment that are linked to revenue from current or future operations as costs or assets, depending on the circumstances of each disbursement. Moreover, we account for disbursements related to past operations, which no longer contribute to current or future revenues, as current period costs. We accrue a liability for a future disbursement when an obligation related to environmental remediation is identified and the amount thereof can be reasonably estimated.

Estimated liabilities for environmental remediation and asset retirement obligations are subject to change as a result of: changes in laws, regulations and their interpretation; the review of additional information on the extent and nature of site contamination; the determination of additional works that need to be undertaken; improvements in technology; the nature and timing of expenditure; foreign currency exchange rates to the extent that some of these costs are incurred in U.S. dollars; and changes in discount rates.

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We do not recognize the obligations related to the costs of future retirement of assets associated with the principal refining processes for gas and petrochemicals. These assets are considered to have an indefinite useful life due to the potential for maintenance and repairs, and, accordingly, we lack sufficient information to reasonably determine the date on which they will be decommissioned.

Financial Instruments

We face market risk caused by the volatility of hydrocarbon prices, exchange rates and interest rates. In order to monitor and manage this risk, Petróleos Mexicanos and the subsidiary entities have developed policies and guidelines that promote an integrated scheme for market risk management, regulate the use of DFIs, guide the development of hedging strategies and provide strategies for the formulation of risk limits.

We enter into derivatives transactions with the sole purpose of hedging financial risks related to our operations. Nonetheless, some of these transactions do not qualify for hedge accounting treatment because they do not meet the strict requirements of IAS 39, “Financial Instruments Recognition and Measurement” for designation as hedges. They are therefore recorded in the financial statements as non-hedge instruments or as instruments entered into for trading purposes, despite the fact that their cash flows are offset by the cash flows of the positions to which they relate. As a result, the changes in their fair value are recognized in the financing cost. See Note 16 to our consolidated financial statements included herein.

Impairment of Non-Financial Assets

At each reporting date, we evaluate whether there is objective evidence that non-financial assets, other than inventory or deferred taxes, are impaired. Significant judgment is required to appropriately assess the recoverable amount, represented by the higher of the value in use and the fair value, less costs to sell or otherwise dispose of our reporting units. Our future net cash flow projections are based on the best available estimates of the cash-generating unit income and expenses using forecasts, prior results and the outlook for the business’s performance and the market’s development. Our annual budget and business plan set macroeconomic forecasts for each of the cash-generating units, which are calculated based on different assumptions regarding projected commodity sales prices, volume of production and overhead costs, foreign currency exchange rates and inflation, among other items, that are used to quantify income and expense estimates. Any change in the assumptions upon which the forecasts for each cash-generating unit are based can materially affect the anticipated cash flows to be generated by non-financial assets.

These estimated future net cash flows are discounted at present value using cash-generating unit specific discount rates determined as a function of the currency in which their respective cash flows are denominated and the risks associated with these cash flows. The discount rates are intended to reflect current market assessments of the time value of money and the risks specific to the asset. Accordingly, the various discount rates used take into consideration country risk. To ensure that the calculations are consistent and avoid double counting, the cash flow projections do not factor in risks that have already been built into the discount rates used. The discount rates used reflect current market conditions and specific risks related to those fixed assets. See Note 3(j) to our consolidated financial statements included herein.

As of December 31, 2017, we have carried out an impairment test to assess the carrying amount of non-financial assets, other than inventories and deferred taxes. The impairment test has resulted in a net impairment of Ps. 151.4 billion, primarily resulting from a Ps. 129.3 billion impairment for Pemex Exploration and Production due to (1) the deferral of the development investments in the first five years of the economic horizon in the proved reserves, (2) insufficient cash flows to make up for costs recovery at the Burgos and Lakach projects resulting from the 4.3% appreciation of the Mexican peso against the U.S. dollar from a peso–U.S. dollar exchange rate of Ps. 20.6640 to U.S. $1.00 as of December 31, 2016 to a peso–U.S. dollar exchange rate of Ps. 19.7867 to U.S. $1.00 as of December 31, 2017, due to the fact that cash inflows are denominated in U.S. dollars and then translated to the reporting currency using the exchange rate at end of the

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period; (3) a 0.3% increase in the discount rate; (4) a 7.2% decrease in crude oil forward prices and (5) the natural decline in production in the Macuspana project. For more information on the impairment of our non-financial assets, see Note 12 to our consolidated financial statements included herein.

Income Taxes

As described under “Item 4—Information on the Company—Taxes, Duties and Other Payments to the Mexican Government” above and in Note 3(n) and Note 20 to our consolidated financial statements included herein, the fiscal regime applicable to Petróleos Mexicanos and the subsidiary entities and certain subsidiary companies as of December 31, 2017 became effective on January 1, 2015. Effective as of this date, the Hydrocarbons Revenue Law and the Federal Revenue Law of the applicable year comprise the fiscal regime applicable to us.

As of December 31, 2017, Petróleos Mexicanos and the subsidiary entities are required to estimate taxable income according to IAS 12, “Income Taxes.” This process involves an estimation of our actual current tax and an assessment of temporary differences resulting from differing treatment of items for tax and accounting purposes. These differences result in deferred assets and liabilities, which are included within our consolidated balance sheet. We must then assess the likelihood that our deferred assets will be recovered from future taxable income.

Management judgment is required in determining our provision for income taxes. In the event that actual results differ from our estimates, any adjustments recorded will affect our net income during the corresponding period.

Exploration and Production Taxes and Duties

The fiscal regime applicable to the exploration and production assignments granted to us by the Mexican Government includes the following taxes and duties:

• Profit-Sharing Duty. The Profit-Sharing Duty is calculated based on the value of hydrocarbons produced in the relevant area minus certain permitted deductions. As of January 1, 2017, the applicable rate of this duty was 67.50%. Pursuant to the Hydrocarbons Revenue Law, the Profit-Sharing Duty decreases on an annual basis and as of January 1, 2019, it is expected to be set at 65%.

• Hydrocarbons Extraction Duty. The Hydrocarbons Extraction Duty is calculated based on a rate that varies according to (i) the type of hydrocarbon (e.g., crude oil, associated natural gas, non-associated natural gas or condensates), (ii) the volume of production and (iii) the relevant market price.

• Exploration Hydrocarbons Duty. The Exploration Hydrocarbons Duty is calculated by applying a quote per square kilometer for each assigned phase of production and extraction phase. Pemex Exploration and Production must make monthly payments of this duty. The Mexican Government is entitled to collect a monthly payment of Ps. 1,214 per square kilometer of non-producing areas. After 60 months, this tax increases to Ps. 2,903.54 per square kilometer for each additional month that the area is not producing. These amounts will be updated on an annual basis in accordance with the national price index.

For more information on the taxes and duties applicable to and paid by Pemex Exploration and Production, see Note 20 to our consolidated financial statements included herein.

Contingencies

In the ordinary course of business, we are named in a number of lawsuits of various types. We evaluate the merit of each claim and assess the likely outcome. Liabilities for loss contingencies are recorded when it is probable that a liability has been incurred and the amount thereof can be reasonably estimated. We do not

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recognize contingent revenues, earnings or assets until their realization is assured. We have not recorded provisions related to ongoing legal proceedings whenever we do not expect an unfavorable resolution in such proceedings, except as disclosed in “Item 8—Financial Information—Legal Proceedings—Civil Actions” and Notes 6 and 25 to our consolidated financial statements included herein.

Employee Benefits

As described under “Item 6—Directors, Senior Management and Employees—Employees” below and in Note 2(m) and Note 17 to our consolidated financial statements included herein, as of January 1, 2016, we are operating both a defined contribution plan and defined benefit pension plan. Until December 31, 2015, we only operated a defined benefit pension plan.

Contribution Plan

Under the defined contribution plan, both we and our employees contribute to each employee’s individual account, in contrast to the existing defined benefit plan, pursuant to which only we contribute. We account for our contributions as costs, expenses or assets. Contributions to the defined contribution plan that are not expected to be fully settled within 12 months after the end of the annual reporting period in which the employee rendered related services will be discounted using the defined benefits plan discount rate.

Benefit Pension Plan

Under the defined benefit pension plan, we are the only contributor to a trust, which is managed separately. We recognize the cost for the defined benefit pension plan based on independent actuarial computations applying the projected unit credit method. Actuarial gains and losses are recognized within other comprehensive results for the period in which they occur. The costs of prior services are recognized within profit or loss for the period in which they are incurred.

Our net obligation with respect to the defined benefit pension plan equals the present value of the defined benefit obligation less the fair value of plan assets for which obligations have yet to be settled. The value of any asset is limited to the present value of the economic benefit represented by the plan reimbursements and reductions in future contributions to the plan.

In addition, other long-term employee benefits include seniority premiums payable for disability, death and survivors’ benefits, medical services, gas and basic food baskets for beneficiaries. Termination benefits are recognized in profit or loss for the year in which they are incurred.

Benefits to employees were approximately 34.6% and 34.3% of our total liabilities as of December 31, 2017 and 2016, respectively, and any adjustments recorded will affect our net income and/or comprehensive net income during the corresponding period.

Recently Issued Accounting Standards

New accounting interpretations and revisions under IFRS that apply to annual periods beginning on or after January 1, 2018, as well as additional standards, amendments or interpretations that, even though not yet effective, could have a material impact on our consolidated financial statements, and a breakdown of the effect of such new accounting interpretations and revisions are disclosed in Note 3(v) to our consolidated financial statements included herein.

Sales Volumes and Prices

The profitability of our operations in any particular accounting period is directly related to the sales volume of, and average realized prices for, the crude oil and natural gas that we sell. These average realized prices for crude oil and natural gas fluctuate from one period to another due to world market conditions and other factors.

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Export Volumes and Prices

Pemex Exploration and Production sells crude oil to PMI, which then sells it to international clients. The volume of crude oil that we export is the volume delivered to international clients as adjusted for water content according to the bill of lading and standard market practice. PMI bases crude oil export price formulas on a basket of international reference prices and a constant set according to specific market conditions. We determine export prices of refined products, petrochemicals and natural gas by reference to market conditions and direct negotiations with our clients.

Significant changes in international crude oil prices directly affect our financial results. The impact of changes in crude oil prices on our refining activities and petrochemicals business depends on:

• the magnitude of the change in crude oil prices;

• how quickly petroleum and petrochemical product prices in international markets adjust to reflect changes in crude oil prices; and

• the extent to which prices in Mexico, where we sell most of our petroleum products and petrochemicals, reflect international prices for those products.

The following table sets forth the weighted average market price per barrel of crude oil that PMI received from exports and the average price of its benchmark, West Texas Intermediate (or WTI) crude oil, for the years indicated. In 2013, the average prices of crude oil that we exported were higher than the average prices of WTI crude oil. As of December 31, 2014, 2015, 2016 and 2017 however, the average price of crude oil that we exported fell below the average price of WTI crude oil, primarily due to the strengthening of the WTI crude oil against the prices of certain benchmark crudes, such as West Texas Sour, Light Louisiana Sweet and Brent Dated, and against the price of high sulfur fuel oil, upon which the pricing formulas for our crude oil are based.    See “Item 4—Information on the Company—Business Overview—International Trading.”

	Year ended December 31,
	2013		2014		2015		2016		2017
	(in dollars per barrel)
West Texas Intermediate crude oil average price	U.S. $	97.99	U.S. $	93.28	U.S. $	48.71	U.S. $	43.34	U.S. $	50.79
PEMEX crude oil weighted average export price		98.44		85.48		43.12		35.65		46.73

Note: The numbers in this table are daily average prices for the full year, which differ from spot prices at year end. On April 27, 2018, the spot price for West Texas Intermediate crude oil was U.S. $68.10 per barrel and the spot price for the PEMEX crude oil basket was an estimated U.S. $60.89 per barrel.

Sources: PMI operating statistics and Platt’s U.S. Marketscan (McGraw-Hill Company).

Domestic Prices

Until December 31, 2017, the formulas used to determine prices for petroleum products and petrochemical products sold in the Mexican market were determined by the Ministry of Finance and Public Credit and the CRE, in accordance with the Federal Public Administration Organic Law, as amended, the Ley de Planeación (Planning Law), the Reglamento Interior (Internal Regulations) of the Ministry of Finance and Public Credit and the Ley de la Comisión Reguladora de Energía (Energy Regulatory Commission Law). The Ministry of Finance and Public Credit and the CRE received input from us and other governmental ministries through committees composed of officers of Petróleos Mexicanos, the subsidiary entities, some of the subsidiary companies, and representatives of various government ministries, including, among others, the Ministry of Finance and Public Credit, the Ministry of Energy, the Secretaría de la Función Pública (Ministry of Public Function, or the SFP) and the Secretaría de Economía (Ministry of Economy). The Ministry of Finance and Public Credit and the CRE determined wholesale and first-hand sale prices based on opportunity cost, which considers international prices,

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and makes adjustments to reflect transportation expenses and differences in the quality of our products relative to international benchmarks. The retail price was determined based on the wholesale price plus the value added tax, the retailer’s margin and freight costs. The Ministry of Finance and Public Credit adjusted prices for petroleum and petrochemical products sold in the Mexican market, so that they are consistent with the Mexican Government’s macroeconomic targets.

As a part of the energy reform, the Mexican Government began to liberalize prices for petroleum and petrochemical products in 2017 and, as of the date of this annual report, domestic fuel prices have been fully liberalized, are now determined according to market forces and may vary without regard to any specific range determined by the Mexican Government. For further information on domestic prices see “Item 4—Business Overview—Industrial Transformation—Refining—Pricing Decrees” and “Item 4—Business Overview—Industrial Transformation—Gas and Aromatics—Pricing Decrees” above.

The following table compares the average prices in nominal terms of selected petroleum and petrochemical products in Mexico for the years indicated:

	2013		2014		2015		2016		2017
Petroleum Products
Unleaded regular gasoline(1)		Ps. 1,398.03		Ps. 1,460.45		Ps. 1,463.02		Ps. 1,460.19		Ps. 1,413.27
Premium gasoline(1)		1,464.83		1,272.73		1,127.40		931.81		1,277.53
Diesel(1)		1,471.28		1,457.16		1,482.90		1,457.27		1,543.52
Jet fuel(1)		1,558.08		1,458.34		1,370.67		1,268.38		1,187.40
Natural Gas(2)		5.57		5.44		6.18		5.81		6.99
Liquified Petroleum(2)		21.57		21.77		22.18		30.43		36.13
Selected Petrochemicals
Ammonia(3)		6,242.51		6,125.17		6,275.83		6,083.33		6,433.61
Polyethylene(3)		17,931.24		20,300.29		19,798.58		23,402.82		22,300.62

(1) Pesos per barrel.

(2) Pesos per hundred cubic feet.

(3) Pesos per ton.

Source: Petróleos Mexicanos.

IEPS Tax, Hydrocarbon Duties and Other Taxes

The following table sets forth the taxes and duties that we recorded for each of the past three years.

	Year ended December 31,
	2015			2016			2017
	(in millions of pesos)(1)
Hydrocarbon extraction duties and others		Ps. 377,087			Ps. 277,162			Ps. 338,044
Income tax		(45,587	)		(12,640	)		(5,064	)
Total		Ps. 331,500			Ps. 264,522			Ps. 332,980

Note: For a description of these taxes and duties, see “Item 4—Information on the Company—Taxes, Duties and Other Payments to the Mexican Government.”Numbers may not total due to rounding.

(1) Figures are stated in nominal pesos.

Source: PEMEX’s audited financial statements, prepared in accordance with IFRS.

Relation to the Mexican Government

Petróleos Mexicanos and the subsidiary entities are public entities of the Mexican Government, rather than Mexican corporations. Therefore, we do not have the power to issue shares of equity securities evidencing ownership interests and are not required, unlike Mexican corporations, to have multiple shareholders. However, our financing obligations do not constitute obligations of and are not guaranteed by the Mexican Government. The President of Mexico appoints five of the ten members of the Board of Directors of Petróleos Mexicanos as representatives of the Mexican Government, including the Secretary of Energy, who serves as the Chairperson of the Board of Directors of Petróleos Mexicanos, and the Secretary of Finance and Public Credit. The President of

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Mexico also appoints five independent members to the Board of Directors of Petróleos Mexicanos, whose appointments are ratified by the Senate.

Pursuant to the Petróleos Mexicanos Law, the consolidated annual budget of Petróleos Mexicanos and the subsidiary entities, including our financing program, must be submitted to the Ministry of Finance and Public Credit, which has the authority to adjust our financial balance goal and the ceiling on our wage and salary expenditures for the fiscal year. The Mexican Government incorporates our consolidated annual budget and financing program into its budget, which the Chamber of Deputies must approve each year. The Mexican Congress has the authority to adjust our annual financial balance goal at any time by amending the applicable law. In addition, any adjustment proposed by the Board of Directors of Petróleos Mexicanos to change our annual financial balance goal or increase the limit on our wage and salary expenditures or our financing program must be approved by the Chamber of Deputies.

Inflation

Mexico experienced high inflation during the 1980s. The annual rate of inflation (as measured by the change in the NCPI) decreased from a high of 159.2% in 1987 to 11.9% in 1992, 8.0% in 1993 and 7.1% in 1994. However, the economic events that followed the devaluation of the peso against the U.S. dollar in late 1994 and 1995, along with turbulence in international financial markets, caused inflation to increase to 52.0% in 1995. After 1995, inflation decreased to 27.7% in 1996 and 15.7% in 1997. The annual inflation rate was, 4.0% in 2013, 4.1% in 2014, 2.1% in 2015, 3.4% in 2016 and 6.8% in 2017.

We do not use inflation accounting, unless the economic environment in which we operate qualifies as “hyperinflationary,” as defined by IFRS. In accordance with IFRS, the threshold for considering an economy hyperinflationary, and consequently, adjusting certain line items in the financial statements for inflation, is reached when the cumulative three-year inflation rate is 100% or more. Because the economic environment in the three-year periods ended December 31, 2015, 2016 and 2017 did not qualify as hyperinflationary, we did not use inflation accounting to prepare our consolidated financial statements as of December 31, 2015, 2016 and 2017 included herein.

Consolidation

Our financial statements consolidate the results of Petróleos Mexicanos, the subsidiary entities and the subsidiary companies. Certain non-material subsidiary companies are not consolidated and are accounted for under either the cost method or the equity method. For a list of the consolidated subsidiary companies, see Note 3(a) and Note 4 to our consolidated financial statements included herein.

Export Agreements

Though Mexico is not a member of OPEC, it has periodically announced increases and decreases in our crude oil exports, reflecting production revisions made by other oil producing countries in order to contribute to crude oil prices stabilization. However, we have not changed our export goals because of announcements made by OPEC since 2004, and we believe that Mexico has no plans to change our current level of crude oil exports.

Results of Operations of Petróleos Mexicanos, the Subsidiary Entities and the Subsidiary Companies—For the Year Ended December 31, 2017 Compared to the Year Ended December 31, 2016

Total Sales

Total sales increased by 30.1%, or Ps. 322.9 billion, in 2017, from Ps. 1,074.1 billion in 2016 to Ps. 1,397.0 billion in 2017, primarily due to an increase in the volume of our domestic and export sales, mainly due to an increase in the average sales prices of our petroleum products for the reasons explained in further detail below.

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Domestic Sales

Domestic sales increased by 30.9% in 2017, from Ps. 670.0 billion in 2016 to Ps. 877.4 billion in 2017, primarily due to an increase in the average prices of fuel oil, diesel, gasoline and liquefied natural gas. Domestic sales of petroleum products increased by 39.6% in 2017, from Ps. 529.3 billion in 2016 to Ps. 738.9 billion in 2017, primarily due to a 34.1% increase in the average price of gasoline, a 60.7% increase in the average price of diesel, a 26.2% increase in the average price of jet fuel and a 78.9% increase in the average price of fuel oil. These price increases were partially offset by a 27.1% decrease in the volume of sales of premium gasoline, primarily due to a decrease in demand from retail service stations and a 15.8% decrease in the volume of sales of liquefied natural gas. Domestic sales of natural gas increased by 19.0% in 2017, from Ps. 59.6 billion in 2016 to Ps. 70.9 billion in 2017, primarily due to a 43.0% increase in the average sales price of natural gas, partially offset by a 16.8% decrease in the volume of sales of natural gas. Domestic sales of liquefied natural gas decreased by 3.7% in 2017, from Ps. 50.9 billion in 2016 to Ps. 49.0 billion in 2017, primarily as a result of a 15.8% decrease in the volume of sales of liquefied natural gas due to the market share loss that resulted from increased competition due to the liberalization of imports that began in 2016, which was partially offset by a 14.4% increase in the average sales price of liquefied natural gas. Domestic petrochemical sales (including sales of certain by-products of the petrochemical production process) decreased by 47.0%, from Ps. 30.2 billion in 2016 to Ps. 16.0 billion in 2017, primarily as a result of a decrease in the volume of sales of polyethylene.

Export Sales

Export sales increased by 28.7% in peso terms in 2017 (with U.S. dollar-denominated export revenues translated to pesos at the exchange rate on the date of the corresponding export sale), from Ps. 395.1 billion in 2016 to Ps. 508.5 billion in 2017. This increase was primarily due to a 33.9% increase in the weighted average Mexican crude oil export price, a 63.4% increase in the export sales of fuel oil, mainly due to an increase in the average sales price of fuel oil, a 4.5% increase in the export sales of naphthas and a Ps. 1,087.8 million increase in the export sales of petrochemical products. This increase in export sales was partially offset by a 2.7% decrease in the volume of export sales of petroleum products.

Excluding the trading activities of the Trading Companies (in order to show only the amount of export sales related to the subsidiary entities), export sales by the subsidiary entities to the Trading Companies and third parties increased by 31.4% in peso terms, from Ps. 327.8 billion in 2016 to Ps. 430.6 billion in 2017. In U.S. dollar terms, excluding the trading activities of the Trading Companies, total export sales (which are U.S. dollar-denominated) increased by 29.7% in 2017, from U.S. $17.5 billion in 2016 to U.S. $22.7 billion in 2017. This was primarily due to the 33.9% increase in the weighted average Mexican crude oil export price. The trading and export activities of the Trading Companies generated additional marginal revenues of Ps. 77.9 billion in 2017, 15.6% higher in peso terms than the Ps. 67.4 billion of additional revenues generated in 2016, mainly due to an increase in the average prices of diesel and gasoline. Export sales of PMI-NASA, one of our principal Trading Companies, increased by 13.6% in 2017, from Ps. 57.9 billion in 2016 to Ps. 65.8 billion in 2017. The weighted average price per barrel of crude oil that PMI sold to third parties in 2017 was U.S. $47.73, or 33.9%, higher than the weighted average price of U.S. $35.63 in 2016.

Crude oil and condensate export sales to PMI accounted for 88.4% of total export sales (excluding the trading activities of the Trading Companies) in 2017, as compared to 88.1% in 2016. These crude oil and condensate sales increased in peso terms by 31.8% in 2017, from Ps. 288.6 billion in 2016 to Ps. 380.5 billion in 2017, and increased in U.S. dollar terms by 29.7 % in 2017, from U.S. $15.5 billion in 2016 to U.S. $20.1 billion in 2017. The weighted average price per barrel of crude oil that Pemex Exploration and Production sold to PMI for export in 2017 was U.S. $47.26, 34.4% higher than the weighted average price of U.S. $35.17 in 2016.

Export sales of petroleum products, including natural gas and natural gas liquids, by our industrial transformation segment to the Trading Companies and third parties decreased from 10.9% of total export sales (excluding the trading activities of the Trading Companies) in 2016 to 10.7% of those export sales in 2017. Export sales of petroleum products, including products derived from natural gas and natural gas liquids,

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increased by 29.2%, from Ps. 35.6 billion in 2016 to Ps. 46.0 billion in 2017, primarily due to an increase in the average sales prices of fuel oil and naphthas. In U.S. dollar terms, export sales of petroleum products, including products derived from natural gas and natural gas liquids, increased by 26.3%, from U.S. $1.9 billion in 2016 to U.S. $2.4 billion in 2017. Export sales of natural gas increased by 3.3%, from Ps. 21.0 million in 2016 to Ps. 21.7 million in 2017, primarily due to an increase in the average sales price of natural gas.

Petrochemical products accounted for the remainder of export sales in 2016 and 2017. Export sales of petrochemical products (including certain by-products of the petrochemical process) increased by Ps. 1,087.8 million in 2017, from Ps. 3,537.5 million in 2016 to Ps. 4,625.3 million in 2017, primarily due to an increase in export sales of Grupo Fertinal in 2017. In U.S. dollar terms, export sales of petrochemical products (including certain by-products of the petrochemical process) decreased by 2.7% in 2017, from U.S. $218.7 million in 2016 to U.S. $212.8 million in 2017.

Services Income

Services income increased by 24.0% in 2017, from Ps. 9.0 billion in 2016 to Ps. 11.1 billion in 2017, primarily as a result of an increase in transportation services provided by Pemex Logistics to CENAGAS and an increase in freight services provided by Pemex Industrial Transformation to third parties.

Cost of Sales

Cost of sales increased by 16.0%, from Ps. 865.8 billion in 2016 to Ps. 1,004.2 billion in 2017. This increase was mainly due to: (1) an increase of Ps. 131.2 billion in purchases of imports, primarily Magna gasoline, diesel and natural gas, mainly due to an increase in the price of imports and an increase in the volume of imports required to meet domestic demand; (2) a Ps. 15.5 billion increase in hydrocarbon exploration and extraction duties and taxes due to higher average sales prices in 2017; (3) a Ps. 9.5 billion increase in operating expenses, mainly due to an increase in expenses for materials and spare parts; and (4) a Ps. 6.2 billion increase in depreciation of fixed assets and amortization of wells, primarily due to the increased value of assets to be depreciated as a result of the partial reversal of the impairment recorded in 2016. This increase was partially offset by a Ps. 26.0 billion decrease in the cost of unsuccessful wells, primarily due to a decrease in investment.

Impairment of Wells, Pipelines, Properties, Plant and Equipment

Impairment of wells, pipelines, properties, plant and equipment increased by Ps. 482.7 billion in 2017, from a net reversal of impairment of Ps. 331.3 billion in 2016 to a net impairment of Ps. 151.4 billion in 2017, mainly due to: (1) the deferral of the development investments in the first five years of the economic horizon in the proved reserves, (2) insufficient cash flows to make up for costs recovery at the Burgos and Lakach projects resulting from the 4.3% appreciation of the Mexican peso against the U.S. dollar from a peso–U.S. dollar exchange rate of Ps. 20.6640 to U.S. $1.00 as of December 31, 2016 to a peso–U.S. dollar exchange rate of Ps. 19.7867 to U.S. $1.00 as of December 31, 2017, due to the fact that cash inflows are denominated in U.S. dollars and then translated to the reporting currency using the exchange rate at the end of the period; (3) a 0.3% increase in the discount rate; (4) a 7.2% decrease in crude oil forward prices, and (5) the natural decline in production in the Macuspana project.

General Expenses

General expenses increased by Ps. 3.9 billion, from Ps. 137.9 billion in 2016 to Ps. 141.8 billion in 2017, mainly due to an increase in administrative expenses relating to the contributions to the defined contribution pension plan and incentives to encourage employees to migrate from the defined benefit pension plan to the defined contribution plan.

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Other Revenues/Expenses, Net

Other revenues, net, decreased by Ps. 17.5 billion in 2017, from other revenues, net, of Ps. 22.7 billion in 2016 to other revenues, net, of Ps. 5.2 billion in 2017. This decrease was primarily due to the recognition of a Ps. 8.4 billion loss in the disposal of wells, pipelines, properties, plant and equipment and a Ps. 3.3 billion loss in the sale of our shares in Repsol. The decrease in other revenues, net, was partially offset by a Ps. 3.1 billion gain from the sale of our 50% interest in Ductos y Energéticos del Norte and the recovery of a Ps. 13.6 million insurance payment relating to an accident that occurred on our Abkatún-A platform in April 2015. For more information on the explosion at the Abkatún-A platform, see “Item 4—Health, Safety and Environmental Performance”.

Financing Income

Financing income increased by Ps. 2.4 billion in 2017, from Ps. 13.8 billion in 2016 to Ps. 16.2 billion in 2017, primarily due to interest on the promissory notes issued by the Mexican Government in relation to our pension liabilities.

Financing Cost

Financing cost increased by 18.8% in 2017, from Ps. 98.8 billion in 2016 to Ps. 117.6 billion in 2017, primarily due to an increase in interest expense in 2017 following higher levels of indebtedness and the 4.3% appreciation of the peso relative to the U.S. dollar in 2017 as compared to 2016.

Derivative Financial Instruments Income (Cost)

Derivative financial instruments income (cost), net, increased by Ps. 39.3 billion, from a net cost of Ps. 14.0 billion in 2016 to a net income of Ps. 25.3 billion in 2017, primarily due to the depreciation of the U.S. dollar relative to other foreign currencies we hedge and the restructuring of certain of our derivative financial instruments.

Exchange Gain, Net

A substantial portion of our indebtedness, 86.6% as of December 31, 2017, is denominated in foreign currencies. Our exchange gain, net, increased by Ps. 277.2 billion in 2017, from an exchange loss of Ps. 254.0 billion in 2016 to an exchange gain of Ps. 23.2 billion in 2017, primarily as a result of a 4.3% appreciation of the peso relative to the U.S. dollar in 2017. Due to the fact that 100.0% of our revenues from are referenced to prices denominated in U.S. dollars, and only 74.0% of our expenses, including financing costs, are linked to U.S. dollar prices, the appreciation of the peso relative to the U.S. dollar had an unfavorable effect on our ability to meet peso-denominated obligations. The value of the peso in U.S. dollar terms appreciated by 4.3% in 2017, from Ps. 20.6640 = U.S. $1.00 on December 31, 2016 to Ps. 19.7867 = U.S. $1.00 on December 31, 2017, as compared to a 20.1% depreciation of the peso in U.S. dollar terms in 2016.

Taxes, Duties and Other

Hydrocarbon extraction duties and other duties and taxes paid increased by 25.9% in 2017, from Ps. 264.5 billion in 2016 to Ps. 333.0 billion in 2017, primarily due to the 34.4% increase in the weighted average price of the Mexican crude oil export price, from U.S. $35.63 per barrel in 2016 to U.S. $47.26 per barrel in 2017. Income related duties and taxes represented 23.8% of total sales in 2017, as compared to 24.6 % of total sales in 2016.

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Net Income/Loss

In 2017, we had a net loss of Ps. 280.9 billion from Ps. 1,397.0 billion in total sales revenues, as compared to a net loss of Ps. 191.1 billion from Ps. 1,074.1 billion in total sales revenues in 2016. This increase in net loss was primarily explained by:

• a Ps. 482.7 billion increase in the impairment of fixed assets;

• a Ps. 68.5 billion increase in taxes and other duties, mainly due to the increase in the weighted average price of the Mexican crude oil export price; and

• a Ps. 17.5 billion decrease in other revenues, net.

This increase was partially offset by:

• a Ps. 322.9 billion increase in total sales, mainly due to the increase in average sales prices of our domestic refined petroleum products and export crude oil;

• a Ps. 277.2 billion increase in exchange gain, net; and

• a Ps. 39.3 billion increase in derivative financial instruments income, net.

Other Comprehensive Results

In 2017, we had a net gain of Ps. 11.5 billion in other comprehensive results, as compared to a net gain of Ps. 127.9 billion in 2016, primarily due to an increase in the reserve for employee benefits that resulted from the decrease in the discount rate and expected rate of return on plan assets used in the actuarial computation method from 8.2% in 2016 to 7.9% in 2017, as well as the effect of employees migrating from the defined benefits pension plan to the defined contribution plan.

Results of Operations of Petróleos Mexicanos, the Subsidiary Entities and the Subsidiary Companies—For the Year Ended December 31, 2016 Compared to the Year Ended December 31, 2015

Total Sales

Total sales decreased by 7.5%, or Ps. 87.7 billion, in 2016, from Ps. 1,161.8 billion in 2015 to Ps. 1,074.1 billion in 2016, primarily due to a decrease in our domestic sales following the decrease in average sales prices of our petroleum products and the decrease in volume of sales of liquefied natural gas in Mexico, in each case, for the reasons explained in further detail below. This decrease in total sales was partially offset by a 8.0% increase in services income.

Domestic Sales

Domestic sales decreased by 10.2% in 2016, from Ps. 746.2 billion in 2015 to Ps. 670.0 billion in 2016, primarily due to a decrease in the average prices of fuel oil, diesel, gasoline and liquefied natural gas. Domestic sales of petroleum products decreased by 9.5% in 2016, from Ps. 585.0 billion in 2015 to Ps. 529.3 billion in 2016, primarily due to a 5.5% decrease in the average price of gasoline, a 15.9% decrease in the average price of diesel, and a 36.5% decrease in the average price of fuel oil as a result of decreased demand from the CFE. These price decreases were partially offset by a 4.3% increase in the volume of sales of gasoline due to an increase in demand from retail service stations and an 8.1% increase in the volume of sales of jet fuel. Domestic sales of natural gas increased by 9.2% in 2016, from Ps. 54.5 billion in 2015 to Ps. 59.5 billion in 2016, primarily due to a 6.4% increase in the volume of sales of natural gas and a 2.9% increase in the average sales price of natural gas. Domestic sales of liquefied natural gas decreased by 34.9% in 2016, from Ps. 78.2 billion in 2015 to Ps. 50.9 billion in 2016, primarily as a result of a 27.1% decrease in the volume of sales of liquefied natural gas due to the market share loss that resulted from increased competition due to the liberalization of imports in 2016 and a 10.8% decrease in the average sales price of liquefied natural gas. Domestic petrochemical sales (including

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sales of certain by-products of the petrochemical production process) increased by 6.0%, from Ps. 28.5 billion in 2015 to Ps. 30.2 billion, primarily as a result of Ps. 2.6 billion in petrochemical sales by Grupo Fertinal.

Export Sales

Export sales decreased by 3.0% in peso terms in 2016 (with U.S. dollar-denominated export revenues translated to pesos at the exchange rate on the date of the corresponding export sale), from Ps. 407.2 billion in 2015 to Ps. 395.1 billion in 2016. This decrease was primarily due to a 7.4% decrease in the volume of petroleum product exports, a 17.4% decrease in the weighted average Mexican crude oil export price, an 18.5% decrease in the export sales of fuel oil, mainly due to a decrease in the average sales price and volume of sales of fuel oil, and a 13.7% decrease in the export sales of naphthas. This decrease in export sales was partially offset by a 2.1% increase in the volume of sales of crude oil and a Ps. 2,920.7 million increase in the volume of sales of petrochemical products.

Excluding the trading activities of the Trading Companies (in order to show only the amount of export sales related to the subsidiary entities), export sales by the subsidiary entities to the Trading Companies and third parties decreased by 0.5% in peso terms, from Ps. 329.6 billion in 2015 to Ps. 327.8 billion in 2016. In U.S. dollar terms, excluding the trading activities of the Trading Companies, total export sales (which are U.S. dollar-denominated) decreased by 16.2% in 2016, from U.S. $20.9 billion in 2015 to U.S. $17.5 billion in 2016. This was primarily due to the 17.4% decrease in the weighted average Mexican crude oil export price and a 2.1% increase in the volume of crude oil exports. The trading and export activities of the Trading Companies generated additional marginal revenues of Ps. 67.4 billion in 2016, 13.2% lower in peso terms than the Ps. 77.5 billion of additional revenues generated in 2015, mainly due to a decrease in the average prices of diesel and gasoline. Export sales of PMI-NASA, one of our principal Trading Companies, decreased by 9.4% in 2016, from Ps. 63.9 billion in 2015 to Ps. 57.9 billion in 2016. The weighted average price per barrel of crude oil that PMI sold to third parties in 2016 was U.S. $35.63, or 17.4%, lower than the weighted average price of U.S. $43.12 in 2015.

Crude oil and condensate export sales to PMI accounted for 88.1% of total export sales (excluding the trading activities of the Trading Companies) in 2016, as compared to 87.4% in 2015. These crude oil and condensate sales increased in peso terms by 0.2% in 2016, from Ps. 288.2 billion in 2015 to Ps. 288.6 billion in 2016, and decreased in U.S. dollar terms by 14.9% in 2016, from U.S. $18.2 billion in 2015 to U.S. $15.5 billion in 2016. The weighted average price per barrel of crude oil that Pemex Exploration and Production sold to PMI for export in 2016 was U.S. $35.17, 17.6% lower than the weighted average price of U.S. $42.70 in 2015.

Export sales of petroleum products, including natural gas and natural gas liquids, by our industrial transformation segment to the Trading Companies and third parties decreased from 12.4% of total export sales (excluding the trading activities of the Trading Companies) in 2015 to 10.9% of those export sales in 2016. Export sales of petroleum products, including products derived from natural gas and natural gas liquids, decreased by 13.0%, from Ps. 40.9 billion in 2015 to Ps. 35.6 billion in 2016, primarily due to a 5.5% decrease in the volume of exports of fuel oil and a 16.8% decrease in the volume of exports of naphtha, as well as a decrease in the average sales price for both products. In U.S. dollar terms, export sales of petroleum products, including products derived from natural gas and natural gas liquids, decreased by 26.1%, from U.S. $2.6 billion in 2015 to U.S. $1.9 billion in 2016. Export sales of natural gas decreased by 23.1%, from Ps. 27.3 million in 2015 to Ps. 21.0 million in 2016. This was primarily due to a decrease in the production of natural gas.

Petrochemical products accounted for the remainder of export sales in 2015 and 2016. Export sales of petrochemical products (including certain by-products of the petrochemical process) increased by Ps. 2,920.7 million in 2016, from Ps. 616.8 million in 2015 to Ps. 3,537.5 million in 2016, primarily due to inclusion of export sales of Grupo Fertinal during 2016. In U.S. dollar terms, export sales of petrochemical products (including certain by-products of the petrochemical process) increased by Ps. 6,208.8 million in 2016, from Ps. 39.2 million in 2015 to Ps. 6,248.0 million in 2016.

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Services Income

Services income increased by 8.0% in 2016, from Ps. 8.3 billion in 2015 to Ps. 9.0 billion in 2016, primarily as a result of an increase in transportation services supplied by Pemex Logistics to CENAGAS and an increase in freight services provided by Pemex Industrial Transformation to third parties.

Cost of Sales

Cost of sales decreased by 2.9%, from Ps. 892.0 billion in 2015 to Ps. 865.8 billion in 2016. This decrease was mainly due to: (1) a Ps. 23.4 billion decrease in operating expenses, primarily due to cost saving measures; (2) a Ps. 25.0 billion decrease in cost of employee benefits, mainly due to the ongoing benefits resulting from the modifications made to our pension regime in 2015; (3) a Ps. 16.9 billion decrease in the amortization of wells as a result of the net effect of the impairment recorded in 2015 of new investments made in 2016; and (4) a Ps. 5.5 billion decrease in hydrocarbon extraction and exploration duties and taxes due to decreased production and lower average sales prices in 2016 as compared to 2015. This decrease was partially offset by (1) a Ps. 46.9 billion increase in the purchases of imports, primarily gasoline and diesel, due to an increase in the price of imports owing to the 20.1% appreciation of the U.S. dollar relative to the peso in 2016 and a 9.3% increase in the volume of imports; and (2) a Ps. 5.9 billion increase in the cost of unsuccessful wells.

Impairment of Wells, Pipelines, Properties, Plant and Equipment

Impairment of wells, pipelines, properties, plant and equipment decreased by Ps. 809.3 billion in 2016, from an impairment of Ps. 477.9 billion in 2015 to a net reversal of Ps. 331.3 billion in 2016, mainly due to the change in the period used to estimate long-term prices of proved reserves and the recoverable amount of fixed assets from 20 to 25 years in accordance with changes to official guidelines; the appreciation of the U.S. dollar relative to the peso; the reallocation of resources to the most highly profitable fields, particularly fields with lower production costs; and an increase in the average price of crude oil.

Net Periodic Cost of Employee Benefits

During 2015, we had a Ps. 196.1 billion increase in employee benefits in connection with the negotiation of our pension regime in 2015 as described in “Item 6—Directors, Senior Management and Employees—Employees.” Ps. 92.2 billion of this benefit was recognized under net periodic cost of employee benefits, and Ps. 103.9 billion was recognized under general expenses. We do not have a similar benefit to record under net periodic cost of employee benefits for 2016.

General Expenses

General expenses increased by Ps. 100.4 billion, from Ps. 37.5 billion in 2015 to Ps. 137.9 billion in 2016. This increase was primarily due to a one-time Ps. 103.9 billion benefit recognized in our cost of employee benefits in connection with the negotiation of our pension regime in 2015 as described in “Item 6—Directors, Senior Management and Employees—Employees.” Excluding this one-time benefit to cost of employee benefits, general expenses decreased by Ps. 3.5 billion, from Ps. 141.4 billion in 2015 to Ps. 137.9 billion in 2016, primarily due to the effects of our 2016 Budget Adjustment Plan.

Other Revenues/Expenses, Net

Other revenues, net, increased by Ps. 23.5 billion in 2016, from other expenses, net, of Ps. 0.9 billion in 2015 to other revenues, net, of Ps. 22.6 billion in 2016. This increase was primarily due to a Ps. 28.4 billion fiscal support from the Ministry of Finance and Public Credit in connection with the Profit-Sharing Duty, due to the decrease in average prices and production of crude oil, and a Ps. 15.2 billion profit from the sale of our 50% interest in Gasoductos de Chihuahua. This increase in other revenues, net was partially offset by an expense of

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Ps. 27.7 billion that was recognized following our transfer of pipelines and other assets to CENAGAS, due to the difference between the book value of these assets and the amount paid by CENAGAS for these assets.

Financing Income

Financing income decreased by Ps. 1.2 billion in 2016, from Ps.15.0 billion in 2015 to Ps. 13.8 billion in 2016, primarily due to a decrease in the amount we were able to invest during the year, which was partially offset by yield derived from the promissory notes issued by the Mexican Government in connection with our pension liabilities.

Financing Cost

Financing cost increased by 45.7% in 2016, from Ps. 67.8 billion in 2015 to Ps. 98.8 billion in 2016, primarily due to an increase in interest expense in 2016 following higher levels of indebtedness and a 20.1% depreciation of the peso against the U.S. dollar in 2016 as compared to 2015.

Derivative Financial Instruments Income (Cost)

Derivative financial instruments income (cost), net, decreased by Ps. 7.4 billion, from a net cost of Ps. 21.4 billion in 2015 to a net cost of Ps. 14.0 billion in 2016, primarily due to a decrease in the appreciation of the U.S. dollar relative to other foreign currencies we hedge, the restructuring of certain of our derivative financial instruments and favorable changes in market variables involved in our calculation of fair value of these instruments, including exchange rates, foreign currency interest rates and our counterparties’ credit spread.

Exchange Loss, Net

A substantial portion of our indebtedness, 83.2% as of December 31, 2016, is denominated in foreign currencies. Our exchange loss increased by Ps. 99.2 billion, from an exchange loss of Ps. 154.8 billion in 2015 to an exchange loss of Ps. 254.0 billion in 2016, primarily as a result of the 5.3% increase in our indebtedness that is denominated in other currencies and the higher rate of depreciation of the peso against the U.S. dollar, which depreciated by 20.1% in 2016 as compared to 16.9% in 2015. However, due to the fact that over 95.7% of our revenues from exports and domestic sales are referenced to prices denominated in U.S. dollars, and only 71.0% of our expenses, including financing costs, are linked to U.S. dollar prices, the depreciation of the peso relative to the U.S. dollar did have a significant effect on our ability to meet U.S. dollar-denominated financial obligations and improved our ability to meet peso-denominated financial obligations in 2016. The value of the peso in U.S. dollar terms depreciated by 20.1% in 2016, from Ps. 17.2065 = U.S. $1.00 on December 31, 2015 to Ps. 20.6640 = U.S. $1.00 on December 31, 2016, as compared to a 16.9% depreciation of the peso in U.S. dollar terms in 2015.

Taxes, Duties and Other

Hydrocarbon extraction duties and other duties and taxes paid decreased by 20.2% in 2015, from Ps. 331.5 billion in 2015 to Ps. 264.5 billion in 2016, primarily due to the 17.4% decrease in the weighted average price of the Mexican crude oil export price, from U.S. $43.12 per barrel in 2015 to U.S. $35.63 per barrel in 2016. Income related duties and taxes represented 24.9% of total sales in 2016, as compared to 24.9% of total sales in 2015.

Net Income/Loss

In 2016, we had a net loss of Ps. 191.1 billion from Ps. 1,079.5 billion in total sales revenues, as compared to a net loss of Ps. 712.6 billion from Ps. 1,166.4 billion in total sales revenues in 2015. This decrease in net loss was primarily explained by:

• a Ps. 809.2 billion decrease in the impairment of fixed assets;

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• a Ps. 67.0 billion decrease in taxes and other duties, mainly due to the decrease in the weighted average price of the Mexican crude oil export price; and

• a Ps. 23.5 billion increase in other revenues, net.

This decrease was partially offset by

• a Ps. 172.3 billion increase in the net periodic cost of employee benefits, mainly due to the one-time Ps. 196.1 billion decrease in pension liabilities recorded in 2015 as a result of modifications made to our pension regime;

• a Ps. 99.2 billion increase in exchange loss, net;

• a Ps. 86.8 billion decrease in total sales, mainly due to the decrease in average sales prices of our petroleum products and the decrease in volume of sales of liquefied natural gas in Mexico; and

• a Ps. 24.9 billion increase in financing costs, net.

Other Comprehensive Results

In 2016, we had a net gain of Ps. 127.9 billion in other comprehensive results, as compared to a net gain of Ps. 88.6 billion in 2015, primarily due to a decrease in the reserve for employee benefits that resulted from the increase in the discount rate and expected rate of return on plan assets used in the actuarial computation method from 7.4% in 2015 to 8.2% in 2016 and Ps. 21.4 in accumulated gains from the foreign currency translation effect.

Changes in Statement of Financial Position of Petróleos Mexicanos, the Subsidiary Entities and the Subsidiary Companies—from December 31, 2016 to December 31, 2017

Assets

Cash and cash equivalents decreased by Ps. 65.7 billion, or 40.2%, in 2017, from Ps. 163.5 billion as of December 31, 2016 to Ps. 97.8 billion as of December 31, 2017. This decrease was mainly due to an increase in payments to suppliers and contractors, payments on our debt instruments and taxes.

Accounts receivable, net, increased by Ps. 37.4 billion, or 28.1%, in 2016, from Ps. 133.2 billion as of December 31, 2016 to Ps. 170.6 billion as of December 31, 2017, primarily due to: (1) a Ps. 19.6 billion increase in accounts receivable, net, from sales to our international customers, mainly due to the 34.4% increase in the weighted average market price per barrel of crude oil during 2017, from U.S. $35.17 per barrel in 2016 to U.S. $46.27 per barrel in 2017; (2) a Ps. 20.5 billion increase in accounts receivable, net, from sales to domestic customers, mainly due to an increase in the sales price of gasoline and fuel oil to the CFE; and (3) a Ps. 3.6 billion increase in accounts receivable from sundry debtors, mainly due to Ps. 2.5 billion as the current portion of the promissory notes issued by the Mexican Government in relation to our pension liabilities. This increase was partially offset by a Ps. 6.3 billion decrease in accounts receivable from tax credits.

Inventories increased by Ps. 17.8 billion, or 39.2%, in 2017, from Ps. 45.9 billion as of December 31, 2016, to Ps. 63.9 billion as of December 31, 2017, mainly due to an increase in the volume of imports of petroleum products to meet domestic demand.

Derivative financial instruments increased by Ps. 25.3 billion in 2017, from Ps. 4.8 billion as of December 31, 2016 to Ps. 30.1 billion as of December 31, 2017. This increase was mainly due to the increase in the fair value of cross-currency swaps as a result of the depreciation of the U.S. dollar relative to the other relevant currencies.

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Wells, pipelines, properties, plant and equipment decreased by Ps. 231.2 billion in 2017, primarily due to a net impairment in the amount of Ps. 151.4 billion. See “—Results of Operations of Petróleos Mexicanos, the Subsidiary Entities and the Subsidiary Companies—For the Year Ended December 31, 2017 Compared to the Year Ended December 31, 2016—Impairment of Wells, Pipelines, Properties, Plant and Equipment” above in this Item 5 for more information.

Deferred taxes increased by Ps. 45.9 billion, or 45.7%, in 2017, from Ps. 100.3 billion as of December 31, 2016 to Ps. 146.2 billion as of December 31, 2017, mainly due to the Ps. 37.2 billion in deferred profit-sharing duty assets and Ps. 7.1 billion of tax-loss carryforwards.

During 2017, restricted cash decreased by Ps. 10.5 due to the disbursement of previously deposited funds following a settlement agreement with COMMISA. As a result, we no longer have any restricted cash.

Liabilities

Total debt, including accrued interest, increased by Ps. 54.7 billion, or 2.8%, in 2017, from Ps. 1,983.2 billion as of December 31, 2016 to Ps. 2,037.9 billion as of December 31, 2017, mainly due to higher levels of indebtedness.

Line items related to suppliers and contractors decreased by Ps. 11.7 billion, or 7.7%, in 2017, from Ps. 151.6 billion as of December 31, 2016 to Ps. 140.0 billion as of December 31, 2017, primarily due to the continued execution of payment programs established during 2016 to address the total outstanding balance of payments due to suppliers and contractors at year end.

Taxes and duties payable increased by Ps. 2.2 billion, or 4.5%, in 2017, from Ps. 48.8 billion as of December 31, 2016 to Ps. 51.0 billion as of December 31, 2017, primarily due to (1) a Ps. 4.6 billion increase in hydrocarbon extraction duties and (2) a Ps. 2.9 billion decrease in the Profit-Sharing Duty and other taxes.

Derivative financial instruments liabilities decreased by Ps. 13.1 billion, or 42.5%, in 2017, from Ps. 30.9 billion as of December 31, 2016 to Ps. 17.8 billion as of December 31, 2017. This decrease was mainly due to a decrease in the fair value of our cross-currency swaps, partially as a result of the depreciation of the U.S. dollar against the other relevant currencies, as well as changes in the maturity and settlement of certain cross-currency swaps.

Employee benefits liabilities increased by Ps. 38.0 billion, or 3.1%, in 2017, from Ps. 1,220.4 billion as of December 31, 2016 to Ps. 1,258.4 billion as of December 31, 2017. This increase was primarily due to (1) recognition of the net periodic cost of employee benefits and active employee transfers; (2) actuarial gains and contributions made to the Fondo Laboral Pemex (Pemex Labor Fund) trust; and (3) payments made for medical and hospital services and post-mortem benefits provided to retired employees and certain of their beneficiaries.

Equity (Deficit), Net

Equity (deficit), net, increased by Ps. 269.3 billion, or 21.8%, in 2017, from negative Ps. 1,233.0 billion as of December 31, 2016 to negative Ps. 1,502.4 billion as of December 31, 2017. This increase was mainly due to (1) our net loss for the year of Ps. 280.9 billion; (2) a Ps. 12.0 billion increase in actuarial gains on employee benefits; and (3) Ps. 6.0 billion in accumulated loss from the foreign currency translation effect.

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Liquidity and Capital Resources

Overview

During 2017, we were able to strengthen our liquidity position by increasing our accounts receivable, decreasing our accounts payable to suppliers and managing our liquidity risk through derivative financial instruments.

Our principal uses of funds in 2017 were primarily the repayment of debt, strengthening our cash flow through the actions listed below, and, to a lesser extent, the acquisition of wells, pipelines, properties, plant and equipment, sale of financial assets and shares, which collectively amounted to Ps. 80.7 billion. We met this requirement primarily with cash provided by cash flows from borrowings, which amounted to Ps. 704.7 billion. During 2017, our net cash flow from operating activities, together with our funds from financing activities, was sufficient to fund our capital expenditures and other expenses. See “—Overview— Redefinition of Petróleos Mexicanos as a State-Owned Productive Company” above for more information and a discussion of actions being taken in response to this imbalance of resources.

For 2017, our capital expenditures decreased by approximately 38.2% from 2016, primarily due to the expected price levels of our products in 2017 and our expected borrowing capacity. Additionally, one of the most critical problems we faced in 2015 and continued to address in 2017 was our accounts payable to suppliers. As of December 31, 2017, we owed our suppliers approximately Ps. 140.0 billion as compared to Ps. 151.6 billion as of December 31, 2016. As of December 31, 2017, we have paid the total outstanding balance due to suppliers and contractors as of December 31, 2016. The average number of days outstanding of our accounts payable decreased from 82 days as of December 31, 2016 to 62 days as of December 31, 2017. Despite these obligations, we believe net cash flows from our operating and financing activities, together with available cash and cash equivalents, will be sufficient to meet our working capital, debt service and capital expenditure requirements in 2018 because, since early 2015, we and the Mexican Government have adjusted investment, taxation and financing plans to address declining oil prices and maintain our financial strength and flexibility as described above under “Redefinition of Petróleos Mexicanos as a State-Owned Productive Company” and as further described below:

• Changes to Our Business Plan. We have implemented certain measures intended to improve our financial situation, including the reduction of our budget in February 2016, the implementation of a plan to reduce costs and the establishment of lines of credit with Mexican development banks.

• Modifying Our Funding Strategy. We have adjusted our financing strategy to diversify our sources of funding.

• Changes to Employee Benefits Plans. We have incentivized our existing employees to migrate from the defined benefits pension plan to the defined contribution plan. For more information, see “—Critical Accounting Policies—Employee Benefits” above.

• Asset Sales. We have sold certain of our non-essential assets to obtain working capital, including the divestiture of our participation in the Ramones II Norte gas pipeline through the sale of our interest in Ductos y Energéticos del Norte, S. de R.L. de C.V., which is expected to be concluded in the first half of 2018.

• Reduction in Outstanding Accounts Payable. As described above, as of December 31, 2017, we have paid the total outstanding balance due to suppliers and contractors as of December 31, 2016.

• No Payment of Dividend. The Mexican Government announced that Petróleos Mexicanos was not required to pay a state dividend in 2017 and will not be required to pay one in 2018. See “Item 4—Taxes, Duties and Other Payments to the Mexican Government—Fiscal Regime for PEMEX—Other Payments to the Mexican Government” above for more information.

The Federal Income Law applicable to us as of January 1, 2017, provides for the incurrence of up to U.S. $8.1 billion in net indebtedness through a combination of domestic and international capital markets offerings and borrowings from domestic and international financial institutions.

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We have a substantial amount of debt, which we have incurred primarily to finance the capital expenditures needed to carry out our capital investment projects. The sharp decline in oil prices that began in late 2014 had a negative impact on our ability to generate positive cash flows, which, together with our continued heavy tax burden, further exacerbated our ability to fund our capital expenditures and other expenses from cash flow from operations. Despite the continuing low price environment and our heavy tax burden, our cash flow from operations in 2017 together with our funds from financing activities were sufficient to fund our capital expenditures and other expenses. We expect that net cash flows from our operations and financing activities will also be sufficient to meet our working capital requirements, debt service and capital expenditures for 2018.

As of December 31, 2017, our total indebtedness, including accrued interest, was approximately Ps. 2,037.9 billion (U.S. $103.0 billion), in nominal terms, which represents a 2.8% increase compared to our total indebtedness, including accrued interest, of approximately Ps. 1,983.2 billion (U.S. $96.0 billion) as of December 31, 2016. Approximately 25.8% of our existing debt as of December 31, 2017, or Ps. 526.5 billion (U.S. $26.6 billion), is scheduled to mature in the next three years. Our working capital increased from a negative working capital of Ps. 68.4 billion (U.S. $3.3 billion) as of December 31, 2016 to a negative working capital of Ps. 25.6 billion (U.S. $1.3 billion) as of December 31, 2017. Our level of debt may increase further in the short or medium term, as a result of new financing activities or future depreciation of the peso as compared to the U.S. dollar, and may have an adverse effect on our financial condition, results of operations and liquidity position. To service our debt, we have relied and may continue to rely on a combination of cash flow from operations, drawdowns under our available credit facilities and the incurrence of additional indebtedness (including refinancings of existing indebtedness). In addition, we are taking actions to improve our financial position, such as those discussed above, particularly through our 2017-2021 Business Plan.

Certain rating agencies have expressed concerns regarding: (1) the total amount of our debt; (2) the increase in our indebtedness over the last several years; (3) our negative free cash flow during 2016, primarily resulting from our significant capital investment projects and the declining price of oil; (4) our substantial unfunded reserve for retirement pensions and seniority premiums, which was equal to Ps. 1,258.4 billion (U.S. $63.6 billion) as of December 31, 2017, and (5) the resilience of our operating expenses notwithstanding the sharp decline in oil prices that began in late 2014. On March 31, 2016, Moody’s Investors Service announced the revision of our global foreign currency and local currency credit ratings from “Baa1” to “Baa3” and changed the outlook for its credit ratings to negative. On August 3, 2017, Fitch Ratings affirmed our credit rating of “BBB+” in both global local and global foreign currency and modified its outlook from negative to stable. On December 18, 2017, Standard & Poor’s affirmed the outlook for our credit ratings as stable and affirmed our global foreign currency credit rating as “BBB+”, but lowered our global local currency credit rating from “A” to “A-”, citing revisions to its methodology for calculating sovereign ratings. On April 12, 2018, Moody’s Investors Service announced the revision of its outlook for our credit ratings from negative to stable.

Any lowering of our credit ratings may have adverse consequences on our ability to access the financial markets and/or our cost of financing. If we were unable to obtain financing on favorable terms or at all, this could hamper our ability to obtain further financing on favorable terms as well as investment in projects financed through debt and impair our ability to meet our principal and interest payment obligations with our creditors. As a result, we may be exposed to liquidity constraints and may not be able to service our debt, which may adversely affect our financial condition and results of operations.

If such constraints occur at a time when our cash flow from operations is less than the resources needed to meet our debt service obligations, in order to provide additional liquidity to our operations, we could be forced to reduce our planned capital expenditures, implement further austerity measures and/or sell additional non-strategic assets in order to raise funds. A reduction in our capital expenditure program could adversely affect our financial condition and results of operations. Such measures may not be sufficient to permit us to meet our obligations.

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Going Concern

Our consolidated financial statements have been prepared under the assumption that we will continue as a going concern. As we describe in Note 2 to our consolidated financial statements, we have experienced certain conditions that have generated material uncertainty that may cast significant doubt on our ability to continue operating as a going concern. We discuss the circumstances that have caused these negative trends, as well our plans in regard to these matters in “Operating and Financial Review and Prospects—Overview” above in this Item 5 and Note 2 to our consolidated financial statements included herein. We continue operating as a going concern, and our consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.

Equity Structure and Mexican Government Contributions

Our total equity as of December 31, 2017 was negative Ps. 1,502.4 billion, and our total capitalization (long-term debt plus equity) totaled Ps. 378.3 billion. During 2017, our total equity decreased by Ps. 269.3 billion from negative Ps 1,233.0 billion as of December 31, 2016, primarily due to (1) our net loss for the year of Ps. 280.9 billion; (2) a Ps. 12.0 billion increase in actuarial gains on employee benefits; and (3) Ps. 6.0 billion in accumulated loss from the foreign currency translation effect.. Under the Ley de Concursos Mercantiles (Commercial Bankruptcy Law of Mexico), Petróleos Mexicanos and the subsidiary entities cannot be subject to a bankruptcy proceeding. In addition, our current financing agreements do not include financial covenants or events of default that would be triggered as a result of our having negative equity.

In 2017, we did not receive any capital contribution from the Mexican Government.

On April 21, 2016, we received a capital contribution of Ps. 26.5 billion from the Ministry of Finance and Public Credit and, on August 3, 2016, the Ministry of Finance and Public Credit informed us that the Mexican Government would assume Ps. 184.2 billion in payment liabilities related to our pensions and retirement plans, following the review performed by an independent expert. In accordance with the Disposiciones de carácter general relativas a la asunción por parte del Gobierno Federal de obligaciones de pago de pensiones y jubilaciones a cargo de Petróleos Mexicanos y sus empresas productivas subsidiarias (General provisions regarding the assumption by the Federal Government of the payment obligations related to pensions and retirement plans of Petróleos Mexicanos and its productive state-owned subsidiaries) published in the Official Gazette of the Federation on December 24, 2015, we received Ps. 184.2 billion in promissory notes issued by the Mexican Government, which replaced the Ps. 50.0 billion promissory note issued to us on December 24, 2015 and was recognized as an increase in equity in the amount of Ps. 135.4 billion in the form of Certificates of Contribution “A.” The Ps. 135.4 billion increase in equity was the result of the Ps. 184.2 billion value of the promissory notes as of June 29, 2016, minus the Ps. 50.0 billion promissory note we received on December 24, 2015, plus a Ps. 1.2 billion increase in the value of the promissory notes from June 29, 2016 to August 15, 2016, which is the date on which we received the promissory notes. On August 15, 2016, we exchanged Ps. 47.0 billion of these promissory notes for short-term floating rate Mexican Government debt securities known as Bonos de Desarrollo del Gobierno Federal (Development Bonds of the Federal Government, or BONDES D). We then sold the BONDES D to Mexican development banks for the same price at which we received them from the Mexican Government.

As of December 31, 2016 and 2017, the balance of Mexican Government contributions to Petróleos Mexicanos was Ps. 140.6 billion. As of December 31, 2016 and 2017, the total amount of contributions in the form of Certificates of Contribution “A” was Ps. 356.5 billion.

Cash Flows from Operating, Financing and Investing Activities

During 2017, net funds provided by operating activities totaled Ps. 63.4 billion, as compared to negative Ps. 41.9 billion in 2016, due to an increase in sales and a lower corresponding increase in cost of sales resulting

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from improvements in our operations. Net loss was Ps. 280.9 billion in 2017, as compared to net loss of Ps. 191.1 billion in 2016. For more information on the reasons for this increase in net loss, see “ —Results of Operations of Petróleos Mexicanos, the Subsidiary Entities and the Subsidiary Companies—For the Year Ended December 31, 2017 Compared to the Year Ended December 31, 2016” above. Our net cash flows used in financing activities totaled Ps. 46.3 billion in 2017, as compared to net cash flows from financing activities of Ps. 211.7 billion in 2016, primarily due to lower financing requirments in 2017 and an increase in interest paid in 2017, as compared to 2016. During 2017, we applied net cash flows of Ps. 80.7 billion for net investments at cost in fixed assets, as compared to our application of cash flows of Ps. 132.5 billion in 2016 for net investments at cost in fixed assets, primarily due to a 38.2% decrease in our capital expenditures in 2017, as compared to 2016.

At December 31, 2017, our cash and cash equivalents totaled Ps. 97.9 billion, as compared to Ps. 163.5 billion at December 31, 2016.

Liquidity Position

We define liquidity as funds available under our lines of credit as well as cash and cash equivalents. The following table summarizes our liquidity position as of December 31, 2016 and 2017.

	As of December 31,
	2017		2016
	(millions of pesos)
Borrowing base under lines of credit		Ps. 130,348		Ps. 99,174
Cash and cash equivalents		97,852		163,533
Liquidity		Ps. 228,200		Ps. 262,707

The following table summarizes our sources and uses of cash for the years ended December 31, 2016 and 2017:

	For the years ended December 31,
	2017		2016
	(millions of pesos)
Net cash flows (used in) from operating activities		Ps. 63,397		Ps. (41,898)
Net cash flows used in investing activities		(80,691)		(132,493)
Net cash flows from financing activities		(46,255)		211,750
Effect of change in cash value		(2,133)		16,804
Net increase (decrease) in cash and cash equivalents		Ps. (65,682)		Ps. 54,143

Note: Numbers may not total due to rounding.

Investment Policies

Our Finance and Treasury Department maintains financial resources sufficient to meet our payment commitments and those of the subsidiary entities, as well as a comprehensive, consolidated cash position and related projections in anticipation of such commitments.

Our investment policies attempt to take advantage of favorable market conditions by accessing the most favorable terms offered to us by financial institutions. Investments of financial resources by our Finance and Treasury Department are made in accordance with the following policies:

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Investments of Mexican Pesos

In connection with investments in Mexican pesos, we are obligated, during the structuring and development phase of our financial transactions, to observe and comply with the investment guidelines for resources in pesos that were approved by our Financial Resources Committee on December 21, 2006, as modified from time to time. We may only invest in the following:

(a) securities issued or guaranteed by the Mexican Government;

(b) securities issued by Sociedades Nacionales de Crédito (National Credit Societies), the balance of which may not exceed 50% of our cash and cash equivalents;

(c) repurchase agreements that use securities issued or guaranteed by the Mexican Government;

(d) time deposits with major financial institutions, the balance of which may not exceed 30% of our cash and cash equivalents; and

(e) shares of mutual funds whose investments are limited to securities issued or guaranteed by the Mexican Government.

In addition to the above limits, demand deposit accounts must be traded with financial institutions that maintain, at a minimum, the following credit ratings as issued by the applicable rating agency:

Domestic scale	Fitch Ratings	S&P	Moody’s
Long term	AA(mex)	mxAA	Aa2.mx
Short term	F1(mex)	A-1	Mx-1

Investments of Financial Resources in Dollars

Investments of financial resources in dollars must meet our operational and strategic requirements and must be previously approved by Banco de México on a case-by-case basis. Currently, our investments in dollars are limited to operational accounts, short-term money market funds and time deposits. Our dollar investments are managed by Banco de México.

Operational Currencies

The main currencies for investing cash and cash equivalents are pesos and dollars. Similarly, we generate revenues from the domestic and international sales of our products in those two currencies and our expenses, including those relating to our debt service, are payable in these two currencies.

Commitments for Capital Expenditures and Sources of Funding

Our current aggregate commitments for capital expenditures for 2018 total approximately Ps. 113.2 billion. For a general description of our current commitments for capital expenditures, see “Item 4—Information on the Company—History and Development—Capital Expenditures.” The amount of our aggregate capital expenditures commitments for 2018 remains subject to adjustment by the Mexican Government. See “Item 3—Key Information—Risk Factors—Risk Factors Related to our Relationship with the Mexican Government—The Mexican Government controls us and it could limit our ability to satisfy our external debt obligations or could reorganize or transfer us or our assets.”

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The following table sets forth our total capital expenditures by segment for the year ended December 31, 2017, and the budget for these expenditures for 2018. For more information see “Item 4—History and Development—Capital Expenditures.”

	Year ended December 31, 2017		Budget 2018(1)
	(millions of pesos)
Exploration and Production		Ps. 85,491		Ps. 81,765
Industrial Transformation(2)		18,576		18,360
Drilling and Services		1,550		1,434
Logistics		4,917		4,449
Fertilizers		264		444
Ethylene		618		1,786
Cogeneration and Services		—		—
Corporate and other Subsidiaries		1,609		4,978
Total		Ps. 113,025		Ps. 113,216

Note: Numbers may not total due to rounding.

(1) Budget presented to the Board of Directors of Petróleos Mexicanos on March 5, 2018.

Our current commitments for capital expenditures have fluctuated in recent years as compared to previous years. Based on past experience, we expect to generate sufficient funds for our working capital, capital expenditures and investments through:

• cash flow generated by operations;

• the issuance of certificados bursátiles (peso-denominated publicly traded notes) in the Mexican market;

• the issuance of debt securities in the international capital markets;

• the renewal of existing lines of credit and the entering into of new lines of credit from international and local commercial banks; and

• other financing activities.

The securities that we issue may vary in tenor, amount, currency and type of interest rate. We may issue debt securities in U.S. dollars, Japanese yen, euros, pounds, pesos or Swiss francs, among others; these securities may be issued with fixed or floating rates and with maturities of one or more years, including perpetual debt securities, depending on market conditions and funding requirements. We may issue securities in the international capital markets or in the Mexican domestic market, or in both markets. Commercial bank syndicated loans may be established with single or multiple tranches with varying maturities. Bilateral loans may vary in tenor and range, which may be of one year or more. See also “—Financing Activities” below.

Financing Activities

2018 Financing Activity. During the period from January 1 to April 27, 2018, we participated in the following activity:

• On February 12, 2018, Petróleos Mexicanos issued U.S. $4,000,000,000 of debt securities under its U.S. $92,000,000,000 Medium-Term Notes Program, Series C, in two tranches: (1) U.S. $2,500,000,000 5.35% Notes due 2028 and (2) U.S. $1,500,000,000 6.35% Bonds due 2048. All debt securities under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

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• On February 12, 2018, Petróleos Mexicanos consummated an exchange offer pursuant to which it exchanged (1) U.S. $952,454,000 aggregate principal amount of its outstanding 5.500% Bonds due 2044 for U.S. $881,899,000 aggregate principal amount of its new 6.350% Bonds due 2048 and (2) U.S. $1,021,065,000 aggregate principal amount of its outstanding 5.6250% Bonds due 2046 for U.S. $946,764,000 aggregate principal amount of its 6.350% Bonds due 2048.

• On March 5, 2018, Petróleos Mexicanos consummated a tender offer pursuant to which it purchased U.S. $138,598,000 aggregate principal amount of its outstanding 3.125% Notes due 2019, U.S. $558,644,000 aggregate principal amount of its outstanding 5.500% Notes due 2019, U.S. $91,843,000 aggregate principal amount of its outstanding 8.000% Notes due 2019, U.S. $183,017,000 aggregate principal amount of its outstanding 6.000% Notes due 2020 and U.S. $817,303,000 aggregate principal amount of its outstanding 3.500% Notes due 2020.

• On March 27, 2018, Petróleos Mexicanos entered into a loan agreement with Atriadius DSB in the amount of U.S. $181,101,291, which bears interest at a floating rate linked to LIBOR and matures in February 2025.

• On April 17, 2018, Petróleos Mexicanos increased its Medium-Term Notes Program from U.S. $92,000,000,000 to U.S. $102,000,000,000.

2017 Financing Activities. During 2017 we participated in the following activities:

• On February 14, 2017, Petróleos Mexicanos issued €4,250,000,000 of debt securities under its U.S. $72,000,000,000 Medium-Term Notes Program, Series C, in three tranches: (1) €1,750,000,000 of its 2.5% Notes due 2021; (2) €1,250,000,000 of its 3.75% Notes due 2024; and (3) €1,250,000,000 of its 4.875% Notes due 2028. All debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

• On April 6, 2017, Petróleos Mexicanos obtained a a loan from a line of credit for U.S. $132,000,000, which bears interest at a fixed rate of 5.25% and matures on April 6, 2024. The line of credit is guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

• On May 15, 2017, Petróleos Mexicanos entered into a term loan credit facility in the amount of U.S. $400,000,000, which bears interest at a floating rate linked to LIBOR (plus 165 basis points) and matures on May 15, 2020. The term loan is guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

• On June 16, 2017, Petróleos Mexicanos increased its Medium-Term Notes Program from U.S. $72,000,000,000 to U.S. $92,000,000,000.

• On July 17, 2017, Petróleos Mexicanos entered into a revolving credit facility in the amount of U.S. $1,950,000,000, which matures in 2020.

• On July 18, 2017, Petróleos Mexicanos issued U.S. $5,000,000,000 of debt securities under its U.S. $92,000,000,000 Medium-Term Notes Program, Series C, in two tranches: (1) U.S. $2,500,000,000 of its 6.50% Notes due 2027 and (2) U.S. $2,500,000,000 of its 6.75% Bonds due 2047. All debt securities under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

• On July 21, 2017, Petróleos Mexicanos consummated a tender offer pursuant to which it purchased U.S. $922,485,000 aggregate principal amount of its outstanding 5.750% Notes due 2018, U.S. $644,374,000 aggregate principal amount of its outstanding 3.500% Notes due 2018 and U.S. $172,591,000 aggregate principal amount of its outstanding 3.125% Notes due 2019.

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• On November 16, 2017, Petróleos Mexicanos issued £450,000,000 of its 3.750% Notes due 2025 under its U.S.$92,000,000,000 Medium-Term Notes Program, Series C. All debt securities under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

• On December 15, 2017, one of our subsidiary companies, Pro-Agroindustria, S.A. de C.V., refinanced a credit line for U.S. $390,000,000, prepaying U.S. $140,000,000 and entering into a new credit line for the outstanding U.S. $250,000,000, which bears interest at a floating rate linked to LIBOR plus 250 basis points on a quarterly basis and matures on June 29, 2018.

• On December 18, 2017, Petróleos Mexicanos entered into a credit line facility in the amount of U.S. $200,000,000, which bears interest at a floating rate linked to LIBOR plus 165 basis points and matures on December 18, 2020.

• On December 21, 2017, Petróleos Mexicanos borrowed U.S. $300,000,000 from a bilateral credit line which bears interest at a floating rate linked to LIBOR plus 175 basis points and matures on December 21, 2022.

As of December 31, 2017, Petróleos Mexicanos had U.S. $6,700,000,000 and Ps. 23,500,000,000 in available revolving credit lines in order to ensure liquidity, with U.S. $5,400,000,000 and Ps. 23,500,000,000 remaining available.

2016 Financing Activities. During 2016 we participated in the following activities:

• On January 25, 2016, Petróleos Mexicanos increased its Medium-Term Notes Program from U.S. $52,000,000,000 to U.S. $62,000,000,000 pursuant to an authorization by the Board of Directors of Petróleos Mexicanos on August 18, 2015.

• On January 28, 2016, subsidiaries of Pemex Fertilizers obtained loans for an aggregate amount of U.S. $635,000,000 in connection with the acquisition of Grupo Fertinal, S.A.

• On February 4, 2016, Petróleos Mexicanos issued U.S. $5,000,000,000 of debt securities under its U.S. $62,000,000,000 Medium-Term Notes Program, Series C, in three tranches: (1) U.S. $750,000,000 of its 5.500% Notes due 2019; (2) U.S. $1,250,000,000 of its 6.375% Notes due 2021; and (3) U.S. $3,000,000,000 of its 6.875% Notes due 2026. All debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services as of the date of this annual report.

• On February 5, 2016, Petróleos Mexicanos obtained a loan from a line of credit for Ps. 7,000,000,000 bearing interest at a floating rate linked to the TIIE, plus 0.55%, which was repaid in full on January 27, 2017.

• On March 15, 2016, Petróleos Mexicanos issued €2,250,000,000 of debt securities under its U.S. $62,000,000,000 Medium-Term Notes Program, Series C in two tranches: (1) €1,350,000,000 of its 3.750% Notes due 2019 and (2) €900,000,000 of its 5.125% Notes due 2023. All debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

• On March 17, 2016, Petróleos Mexicanos received a disbursement of Ps. 2,000,000,000 from its revolving credit lines at a floating rate linked to the TIIE, which was repaid in full on March 17, 2017.

• On March 17, 2016, Petróleos Mexicanos received a disbursement of Ps. 3,300,000,000 from its revolving credit lines at a floating rate linked to the TIIE, which was repaid in full on March 17, 2017.

• On March 23, 2016, Petróleos Mexicanos issued in the Mexican market Ps. 5,000,000,000 of Certificados Bursátiles under its Ps. 200,000,000,000 Unidades de Inversión (or UDI) equivalent Certificados Bursátiles Program, at a floating rate linked to the TIIE due 2019. All debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services as of the date of this annual report.

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• On March 28, 2016, Petróleos Mexicanos borrowed Ps. 9,700,000,000 from a credit line at a floating rate linked to the TIIE, which was repaid in full on March 28, 2017.

• On April 19, 2016, Petróleos Mexicanos borrowed €500,000,000 from a credit line at a fixed rate of 5.11%, which matures on March 15, 2023.

• On May 31, 2016, Petróleos Mexicanos borrowed U.S. $300,000,000 from a bilateral credit line which bears interest at a floating rate linked to the LIBOR, which matures on May 31, 2021.

• On June 14, 2016, Petróleos Mexicanos issued CFH 375,000,000 aggregate principal amount of Notes under its U.S. $62,000,000,000 Medium-Term Notes Program, Series C, in two tranches: (1) CFH 225,000,000 of its 1.500% Notes due 2018 and (2) CFH 150,000,000 of its 2.375% Notes due 2021. All debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services as of the date of this annual report.

• On June 17, 2016, Pemex Exploration and Production obtained approximately U.S. $1.1 billion in connection with the sale and leaseback of certain infrastructure assets used for oil and gas activities. As part of this transaction, Pemex Exploration and Production entered into a 15-year financial lease agreement pursuant to which Pemex Exploration and Production will retain the operation of these assets and the title and ownership of such assets will revert to Pemex Exploration and Production at the end of this period following payment of an agreed price.

• On July 8, 2016, Pemex Industrial Transformation obtained approximately U.S. $600,000,000 in connection with the sale and leaseback of a plant located in the Madero Refinery. As part of this transaction, Pemex Industrial Transformation entered into a 20-year financial lease agreement pursuant to which Pemex Industrial Transformation will retain the operation of this plant and the title and ownership will revert to Pemex Industrial Transformation at the end of this period following payment of an agreed price. This transaction was recognized as a financing activity due to the fact that we retained all of the risks and benefits associated with ownership of the asset and substantially all of the operating rights of the asset.

• On July 26, 2016, Petróleos Mexicanos issued ¥80,000,000,000 of its 0.54% Bonds due 2026. The Bonds are guaranteed by the Japan Bank for International Cooperation.

• On September 21, 2016, Petróleos Mexicanos issued U.S. $4,000,000,000 of its debt securities under its U.S. $62,000,000,000 Medium-Term Notes Program, Series C, in two tranches: (i) U.S. $2,000,000,000 of its 4.625% Notes due 2023 and (ii) U.S. $2,000,000,000 of its 6.750% Bonds due 2047. All debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services as of the date of this annual report.

• On October 3, 2016, Petróleos Mexicanos consummated a tender and exchange offer pursuant to which it (i) purchased U.S. $687,725,000 aggregate principal amount of its outstanding 8.000% Notes due 2019 and U.S. $657,050,000 aggregate principal amount of its outstanding 5.750% Notes due 2018 and (ii) exchanged (a) U.S. $73,288,000 aggregate principal amount of its outstanding 5.750% Notes due 2018 for U.S. $69,302,000 aggregate principal amount of its 4.625% Notes due 2023 and U.S. $8,059,000 aggregate principal amount of its 6.750% Bonds due 2047 and (b) U.S. $1,591,961,000 aggregate principal amount of its outstanding 5.500% Bonds due 2044 for U.S. $1,491,941,000 aggregate principal amount of its 6.750% Bonds due 2047. The 4.625% Notes due 2023 and 6.750% Bonds due 2047 are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services and represent reopenings of the 4.625% Notes due 2023 and 6.750% Bonds due 2047, respectively, originally issued on September 21, 2016.

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• On December 6, 2016, Petróleos Mexicanos increased its Medium-Term Notes Program, Series C, from U.S. $62,000,000,000 to U.S. $72,000,000,000.

• On December 13, 2016, Petróleos Mexicanos issued U.S. $5,500,000,000 of its debt securities under its U.S. $72,000,000,000 Medium-Term Notes Program, Series C in three tranches: (1) U.S. $3,000,000,000 at a fixed rate of 6.50% due 2027, (2) U.S. $1,500,000,000 at a fixed rate of 5.375% due 2022, and (3) U.S. $1,000,000,000 at a floating rate linked to LIBOR plus 365 basis points, due 2022. All debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services as of the date of this annual report.

• On December 14, 2016, Petróleos Mexicanos entered into a term loan credit facility in the amount of U.S. $300,000,000 at a floating rate linked to LIBOR plus 165 basis points, which matures on December 6, 2019.

• Between January 1 and December 31, 2016, P.M.I. Holdings B.V. obtained U.S. $11,369,800 in financing from its revolving credit lines, which was repaid in full. As of December 31, 2016, there was no outstanding amount under this revolving credit line.

As of December 31, 2016, Petróleos Mexicanos had U.S. $4,750,000,000 and Ps. 23,500,000,000 in available revolving credit lines in order to ensure liquidity, with U.S. $4,630,000,000 and Ps. 3,500,000,000 remaining available.

Indebtedness

During 2017, our total debt increased by 2.8%, from Ps. 1,983.2 billion at December 31, 2016 to Ps. 2,037.9 billion at December 31, 2017, primarily due to the financing activities undertaken during this period, as described in Note 15 to our consolidated financial statements included herein.

As of December 31, 2017 and as of the date of this annual report, we were not in default on any of our financing agreements.

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The following table sets forth the analysis of our total indebtedness (not including accrued interest) as of December 31, 2017 based on short- and long-term debt and fixed or floating rates:

	In millions of U.S. dollars
Short-term debt
Short-term bonds with floating interest rates	U.S. $	693
Lines of credit with variable interest rates established under committed credit facilities with various international commercial banks		2,698
Lines of credit with fixed interest rates		2,933
Total short-term debt(1)	U.S. $	6,324
Long-term debt
Fixed rate instruments
Instruments with fixed annual interest rates ranging from 0.5% to 9.5% and maturities ranging from 2019 to 2047 and perpetual bonds with no maturity date	U.S. $	83,239
Variable rate instruments
Drawings under lines of credit based on LIBOR and other variable rates with maturities ranging from 2019 to 2030		8,038
Floating rate notes with maturities ranging from 2019 to 2025		3,770
Total variable rate instruments		11,808
Total long-term debt		95,047
Total indebtedness(1)	U.S. $	101,371

Note: Numbers may not total due to rounding.

(1) Excludes U.S. $1,620.5 million of accrued interest and includes notes payable to contractors.

The table below sets forth our total indebtedness as of December 31 for each of the three years from 2015 to 2017.

Total Indebtedness of PEMEX

	As of December 31,(1)
	2015		2016		2017
	(in millions of U.S. dollars)(2)
Domestic debt in various currencies	U.S. $	19,415	U.S. $	16,651	U.S. $	13,595
External debt in various currencies(3)
Bonds(4)		52,981		67,523		76,007
Direct loans		7,486		3,808		6,244
Project financing(5)		4,816		4,125		3,284
Financial leases		536		2,181		2,036
Notes payable to contractors		483		338		205
Total external debt	U.S. $	66,302	U.S. $	77,975	U.S. $	87,776
Total indebtedness	U.S. $	85,717	U.S. $	94,626	U.S. $	101,371

Note: Numbers may not total due to rounding.

(1) Figures do not include accrued interest. Accrued interest was U.S. $1,074.5 million, U.S. $1,346.1 million and U.S. $1,602.5 million at December 31, 2015, 2016 and 2017, respectively.

(2) Indebtedness payable in currencies other than U.S. dollars was first converted into pesos for accounting purposes at the exchange rates set by Banco de México and then converted from pesos to U.S. dollars at the following exchange rates:    Ps. 17.2065 = U.S. $1.00 for 2015, Ps.20.6640 = U.S. $1.00 for 2016 and Ps. 19.7867 = $1.00 for 2017. See Notes 3 and 15 to our consolidated financial statements included herein.

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(3) Indebtedness payable other than in pesos and owed to persons or institutions having their head offices or chief places of business outside of Mexico and payable outside the territory of Mexico.

(4) Includes, as of December 31, 2015 , 2016 and 2017, U.S. $0.28 billion, U.S. $0.16 billion and U.S. $0.06 billion, respectively, of bonds issued by Pemex Finance, Ltd. See “—Financing Activities of Pemex Finance, Ltd.” below.

(5) All credits included in this line are insured or guaranteed by export credit agencies.

Source: PEMEX’s consolidated financial statements, prepared in accordance with IFRS.

Financing Activities of Pemex Finance, Ltd.

Commencing on December 1, 1998, Petróleos Mexicanos, Pemex-Exploration and Production, PMI and P.M.I. Services, B.V. have entered into several agreements with Pemex Finance, Ltd. Under these contracts, Pemex Finance, Ltd. purchases certain existing PMI accounts receivable for crude oil as well as certain accounts receivable to be generated in the future by PMI related to crude oil. The receivables sold are those generated by the sale of Maya and Altamira crude oil to designated customers in the United States, Canada and Aruba. The net proceeds obtained by Pemex Exploration and Production, which assumed all of the rights and obligations of Pemex-Exploration and Production under these agreements, from the sale of such receivables under the agreements are utilized for capital expenditures. Pemex Finance, Ltd. obtains resources for the acquisition of such accounts receivable through the placement of debt instruments in the international markets.

On July 1, 2005, we entered into an option agreement with BNP Paribas Private Bank and Trust Cayman Limited giving us an option to acquire 100% of the shares of Pemex Finance, Ltd. As a result, the financial results of Pemex Finance, Ltd. under IFRS are consolidated into our financial statements, and PMI’s sales of accounts receivable to Pemex Finance, Ltd. have been reclassified as debt. Our option to purchase the shares of Pemex Finance, Ltd. can only be exercised once its remaining debt, approximately U.S. $162.5 million in aggregate principal amount as of December 31, 2016, has been redeemed.

As of December 31, 2017, the outstanding debt of Pemex Finance, Ltd. was composed of U.S. $62.5 million aggregate principal amount of fixed rate notes with maturities in 2018 and interest rates between 9.15% and 10.61% and accrued interest of U.S. $3.5 million.

2018 Financing Activities. During the first four months of 2018, Pemex Finance, Ltd. made payments of U.S. $15.6 million in principal of its notes. Pemex Finance, Ltd. did not incur any additional indebtedness during the first four months of 2018.

2017 Financing Activities. During 2017, Pemex Finance, Ltd. made payments of U.S. $100.0 million in principal of its notes. Pemex Finance, Ltd. did not incur any additional indebtedness during 2017.

2016 Financing Activities. During 2016, Pemex Finance, Ltd. made payments of U.S. $28.1 million in principal of its notes. Pemex Finance, Ltd. did not incur any additional indebtedness during 2016.

Contractual Obligations and Off-Balance Sheet Arrangements

Information about our long-term contractual obligations and off-balance sheet arrangements outstanding as of December 31, 2017 is set forth below. This information is important in understanding our financial position. In considering the economic viability of investment opportunities we view any source of financing, for example, operating leases or sales of future accounts receivable, as being economically equivalent to consolidated debt.

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Contractual Obligations as of December 31, 2017⁽¹⁾

			Payments due by period
	Total		Less than 1 year		1-3 years		4-5 years		After 5 years
	(in millions of U.S. dollars)
Contractual obligations recognized in balance sheet:
Debt(2)		U.S. $100,751		U.S. $7,679		U.S. $18,353		U.S. $17,059		U.S. $57,660
Notes payable to contractors(3)		205		110		53		42		—
Capital lease obligations(4)		2,036		156		260		287		1,333
Other long-term liabilities:
Dismantlement and abandonment costs obligations(5)		3,477		13		478		543		2,443
Employee benefits plan(6)		63,600		3,150		6,542		7,311		46,597
Total contractual obligations recognized in balance sheet		170,069		11,108		25,686		25,242		108,033
Other contractual obligations not recognized in liabilities:
Infrastructure works contracts(7)		35,322		11,611		9,923		6,224		7,564
Financed Public Works Contracts (FPWC)(8)		627		280		96		94		157
Nitrogen supply contracts(9)		379		39		79		79		182
Total contractual obligations not recognized in liabilities(10)		36,328		11,930		10,098		6,397		7,903
Total contractual obligations		U.S. $206,397		U.S. $23,038		U.S. $35,784		U.S. $31,639		U.S. $115,936

Note: Numbers may not total due to rounding.

(1) All amounts calculated in accordance with IFRS.

(2) See Note 15 to our consolidated financial statements included herein. Figures in this line item do not include notes payable to contractors and capital lease obligations, which are presented in separate line items, but do include accrued interest as of December 31, 2017.

(3) See Note 15 to our consolidated financial statements included herein.

(4) See Note 15 to our consolidated financial statements included herein.

(5) See Notes 3(l) and 12(c) to our consolidated financial statements included herein.

(6) See Note 17 to our consolidated financial statements included herein.

(7) See Note 24(e) to our consolidated financial statements included herein.

(8) The amounts presented for Financed Public Works Contracts in this table correspond to works the performance and delivery of which by the relevant contractors are pending. For more information on the FPWC program, see “Item 4—Information on the Company—Business Overview—Pemex Exploration and Production—Integrated Exploration and Production Contracts and Financed Public Works Contracts” and Note 24(c) to our consolidated financial statements included herein.

(9) See Notes 24(b) to our consolidated financial statements included herein.

(10) No amounts have been included for Integrated E&P Contracts in this table, since payments for these contracts will be made on a per-barrel basis and performance and delivery by the relevant contractors is pending. For more information on the Integrated E&P Contracts program, see “Item 4—Information on the Company—Business Overview—Pemex Exploration and Production—Integrated Exploration and Production Contracts and Financed Public Works Contracts” and Note 24(d) to our consolidated financial statements included herein.

Source: PEMEX’s consolidated financial statements, prepared in accordance with IFRS.

As of December 31, 2017, we did not have any off-balance sheet arrangements of the type that we are required to disclose under Item 5.E of Form 20-F. See “Item 11—Quantitative and Qualitative Disclosures about Market Risk.”

Results of Operations by Business Segment

This section presents the results of our operations by business segment, including our central corporate operations and the operations of the consolidated subsidiary companies.

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As further described under “Item 4— Information on the Company—History and Development—Energy Reform—Corporate Reorganization” and in Note 1 and Note 5 to our consolidated financial statements included herein, as a result of the energy reform, we have undergone a corporate reorganization that created new business segments and redistributed the operation of certain business units to different business segments. Accordingly, the results for the business segments presented as of and for the years ended December 31, 2017 and 2016 reflect different business segments from those presented as of and for the year ended December 31, 2015. Further, as of 2016, the results for refining, gas and basic petrochemicals and petrochemicals, which were previously presented separately, are presented as part of the industrial transformation segment. For comparison purposes, we have consolidated 2015 results for these prior segments under “Total industrial transformation.”

Revenue by Business Segment

The following table sets forth our trade and intersegment net sales revenues by business segment for the fiscal years ended December 31, 2015, 2016 and 2017 as well as the percentage change in sales revenues for those years.

	Year Ended December 31,						2016			2017
	2015		2016		2017		vs. 2015			vs. 2016
	(in millions of pesos)(1)						(%)			(%)
Exploration and Production(4)
Trade sales(2)		—		—		—		—			—
Intersegment sales		Ps.690,642		Ps.616,381		Ps. 762,637		(10.8	)		23.7
Total net sales		690,642		616,381		762,637		(10.8	)		23.7
Industrial Transformation(5)
Refining(6)
Trade sales(2)(3)		589,548		n.a.		n.a.		n.a.			n.a.
Intersegment sales		54,876		n.a.		n.a.		n.a.			n.a.
Total net sales		644,424		n.a.		n.a.		n.a.			n.a.
Gas and Basic Petrochemicals(7)
Trade sales(2)(3)		137,456		n.a.		n.a.		n.a.			n.a.
Intersegment sales		55,594		n.a.		n.a.		n.a.			n.a.
Total net sales		193,050		n.a.		n.a.		n.a.			n.a.
Petrochemicals(8)
Trade sales(2)		20,735		n.a.		n.a.		n.a.			n.a.
Intersegment sales		15,824		n.a.		n.a.		n.a.			n.a.
Total net sales		36,559		n.a.		n.a.		n.a.			n.a.
Total Industrial Transformation
Total trade sales		747,739		653,654		863,573		(12.6	)		32.1
Total intersegment sales		126,264		117,096		150,360		(7.3	)		28.4
Total net sales		874,033		770,750		1,013,933		(11.8	)		31.6
Drilling and Services(9)
Trade sales(2)		n.a		70		42		100.0			(40.0	)
Intersegment sales		1,512		1,982		3,400		31.1			71.5
Total net sales		1,512		2,052		3,442		35.7			67.7
Logistics(10)
Trade sales(2)		10,356		2,814		3,715		(72.8	)		32.0
Intersegment sales		599		68,317		70,672		11,305.2			3.4
Total net sales		10,955		71,131		74,387		549.3			4.6

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	Year Ended December 31,									2016			2017
	2015			2016			2017			vs. 2015			vs. 2016
	(in millions of pesos)(1)									(%)			(%)
Cogeneration and Services(11)
Trade sales(2)		0			133			335			100.0			151.9
Intersegment sales		0			52			114			100.0			119.2
Total net sales		0			184			449			100.0			142.7
Fertilizers(12)
Trade sales(2)		1,496			3,875			4,125			159.0			6.5
Intersegment sales		209			900			643			330.8			(28.6	)
Total net sales		1,705			4,776			4,768			180.1			(0.1	)
Ethylene(13)
Trade sales(2)		4,569			15,453			12,648			238.2			(18.2	)
Intersegment sales		474			1,764			1,566			272.2			(11.2	)
Total net sales		5,043			17,217			14,214			241.4			(17.4	)
Trading Companies
Trade sales(2)(3)		407,876			395,354			508,606			(3.1	)		28.6
Intersegment sales		353,137			405,293			539,193			14.8			33.0
Total net sales		761,013			800,648			1,047,799			5.2			30.9
Corporate and other subsidiary companies
Trade sales(2)(3)		(10,275	)		2,740			3,985			(126.7	)		45.4
Intersegment sales and eliminations		(1,172,868	)		(1,211,785	)		(1,528,585	)		3.3			26.1
Total net sales		(1,183,143	)		(1,209,045	)		(1,524,600	)		2.2			26.1
Total net sales		Ps. 1,161,760			Ps. 1,074,093			Ps. 1,397,029			(7.5	)		30.1

Note: Numbers may not total due to rounding.

n.a. Not available.

(1) Figures for 2015, 2016 and 2017 are stated in nominal pesos.

(2) Trade sales represent sales to external customers. See “Item 3—Key Information—Selected Financial Data.”

(3) Includes services income.

(4) Figures for the exploration and production segment for the year ended December 31, 2015 include net sales revenue related to the drilling and services segment until the formation of Pemex Drilling and Services on August 1, 2015 and to the logistics segment until the formation of Pemex Logistics on October 1, 2015.

(5) Figures for the industrial transformation segment for the year ended December 31, 2015 include net sales revenue related to refining, gas and basic petrochemicals and petrochemicals.

(6) Net sales revenue for refining for the years ended December 31, 2016 and 2017 has been included under the industrial transformation segment.

(7) Net sales revenue for gas and basic petrochemicals for the years ended December 31, 2016 and 2017 has been included under the industrial transformation segment.

(8) Figures for petrochemicals for the year ended December 31, 2015 include net sales revenue related to the ethylene segment until the formation of Pemex Ethylene on October 1, 2015 and to the fertilizers segment until the formation of Pemex Fertilizers on October 1, 2015. Net sales revenue for petrochemicals for the year ended December 31, 2016 has been included under the industrial transformation segment.

(9) Figures for the drilling and services segment for the year ended December 31, 2015 refer to net sales revenue since August 1, 2015 when Pemex Drilling and Services was formed.

(10) Figures for the logistics segment for the year ended December 31, 2015 refer to net sales revenue since October 1, 2015 when Pemex Logistics was formed.

(11) Figures for the cogeneration and services segment year ended December 31, 2015 refer to net sales revenue since June 1, 2015 when Pemex Cogeneration and Services was formed.

(12) Figures for the fertilizers segment for the year ended December 31, 2015 refer to net sales revenue since October 1, 2015 when Pemex Fertilizers was formed.

(13) Figures for the ethylene segment for the year ended December 31, 2015 refer to net sales revenue since October 1, 2015 when Pemex Ethylene was formed.

Source: PEMEX’s consolidated financial statements, prepared in accordance with IFRS.

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Income by Business Segment

The following table sets forth our net income (loss) by business segment for each year in the three-year period ended December 31, 2017, as well as the percentage change in income for the years 2015 to 2017.

	Year Ended December 31,									2016 vs. 2015			2017 vs. 2016
	2015			2016			2017			(%)			(%)
	(in millions of pesos)(1)
Business Segment
Exploration and Production(2)		Ps.(667,394)			Ps.(45,879)			Ps. (151,037)			(93.1	)		229.2
Industrial Transformation(3)
Refining(4)		(113,147	)		n.a.			n.a.			n.a.			n.a.
Gas and Basic Petrochemicals(5)		18,126			n.a.			n.a.			n.a.			n.a.
Petrochemicals(6)		7,812			n.a.			n.a.			n.a.			n.a.
Total Industrial Transformation		(87,209	)		(69,865	)		(55,787	)		(19.9	)		(20.2	)
Drilling and Services(7)		455			(142	)		1,266			(131.3	)		(988.7	)
Logistics(8)		(3,685	)		(10,018	)		(834	)		171.8			(91.7	)
Cogeneration and Services(9)		(57	)		(35	)		(92	)		(39.5	)		165.4
Fertilizers(10)		(145	)		(1,659	)		(4,270	)		1,043.7			157.3
Ethylene(11)		(1,755	)		2,097			(1,442	)		(219.5	)		(168.8	)
Trading Companies		8,697			11,167			12,045			28.4			7.9
Corporate and other subsidiary companies(12)		38,526			(76,809	)		(80,699	)		(299.4	)		5.1
Total net income (loss)		Ps. (712,567	)		Ps. (191,144	)		Ps. 280,851			(73.2	)		46.9

Note: Numbers may not total due to rounding.

n.a. not available.

(1) Figures are stated in nominal pesos. See “Item 3—Key Information—Selected Financial Data.”

(2) Figures for the exploration and production segment for the year ended December 31, 2015 include net income (loss) related to the drilling and services segment until the formation of Pemex Drilling and Services on August 1, 2015 and to the logistics segment until the formation of Pemex Logistics on October 1, 2015.

(3) Figures for the industrial transformation segment for the year ended December 31, 2015 include net income (loss) related to refining, gas and basic petrochemicals and petrochemicals.

(4) Net income (loss) for refining for the years ended December 31, 2016 and 2017 has been included under the industrial transformation segment.

(5) Net income (loss) for gas and basic petrochemicals for the years ended December 31, 2016 and 2017 has been included under the industrial transformation segment.

(6) Figures for petrochemicals for the year ended December 31, 2015 include net income (loss) related to the ethylene segment until the formation of Pemex Ethylene on October 1, 2015 and to the fertilizers segment until the formation of Pemex Fertilizers on October 1, 2015. Net income (loss) for petrochemicals for the years ended December 31, 2016 and 2017 has been included under the industrial transformation segment.

(7) Figures for the drilling and services segment for the year ended December 31, 2015 refer to net income (loss) since August 1, 2015 when Pemex Drilling and Services was formed.

(8) Figures for the logistics segment for the year ended December 31, 2015 refer to net income (loss) since October 1, 2015 when Pemex Logistics was formed.

(9) Figures for the cogeneration and services segment year ended December 31, 2015 refer to net income (loss) since June 1, 2015 when Pemex Cogeneration and Services was formed.

(10) Figures for the fertilizers segment for the year ended December 31, 2015 refer to net income (loss) since October 1, 2015 when Pemex Fertilizers was formed.

(11) Figures for the ethylene segment for the year ended December 31, 2015 refer to net income (loss) since October 1, 2015 when Pemex Ethylene was formed.

(12) Includes intersegment eliminations.

Source: PEMEX’s consolidated financial statements, prepared in accordance with IFRS.

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2017 compared to 2016

We present below the results of our operations by business segment. For more information on our operating segments, see “Item 4— Information on the Company—History and Development—Energy Reform—Corporate Reorganization” and Note 1 to our consolidated financial statements included herein. For a detailed description of the financial results of each segment, see Note 1 and Note 5 to our consolidated financial statements included herein.

Exploration and Production

In 2017, total intersegment sales, which include sales to our industrial transformation segment and the Trading Companies, increased by 23.7%, primarily due to the increase in crude oil export prices. As compared to 2016, our exploration and production segment’s sales of crude oil to the Trading Companies in 2017 increased by 40.0% in U.S. dollar terms, primarily due to an increase in exports to the United States and an increase in crude oil export prices. The weighted average price of crude oil sold by our exploration and production segment to the Trading Companies for export was U.S. $47.26 in 2017, as compared to U.S. $35.17 in 2016. Net loss related to exploration and production activities increased by 229.2%, or Ps. 105,158 million, from a Ps. 45,879 million loss in 2016 to a Ps. 151,037 million loss in 2017, primarily due to net impairment of our fixed assets in this segment.

Industrial Transformation

In 2017, trade sales related to industrial transformation activities increased by 32.1%, from Ps. 653,654 million in 2016 to Ps. 863,573 million in 2017, primarily due to an increase in the average sales prices of petroleum products. Intersegment sales increased by 28.4%, from Ps. 117,096 million in 2016 to Ps. 150,360 million in 2017, primarily due to an increase in the prices of petroleum products sold. In 2017, our net loss related to industrial transformation activities was Ps. 55,787 million, 20.2% lower than the loss of Ps. 69,865 million in 2016. The decrease in loss was primarily due to a decrease in cost and operating expenses.

Drilling and Services

In 2017, total sales related to the drilling and services segment increased by 67.7%, from Ps. 2,052 million in 2016 to Ps. 3,442 million in 2017. This increase was primarily due to an increase in services provided to Pemex Exploration and Production. Net income related to drilling and services increased by Ps. 1,408 million, from a loss of Ps. 142 million in 2016 to a net income of Ps. 1,266 million in 2017, primarily due to an increase in foreign exchange income.

Logistics

In 2017, total sales related to the logistics segment increased by Ps. 3,256 million, from Ps. 71,131 million in 2016 to Ps. 74,387 million in 2017, primarily due to an increase in the services provided to Pemex Industrial Transformation. In 2017, our net loss related to logistics activities was Ps. 834 million, a 91.7% decrease as compared to the loss of Ps. 10,018 million in 2016. The decrease in net loss was primarily due to our foreign exchange income.

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Cogeneration and Services

In 2017, total sales related to our cogeneration and services segment increased by Ps. 264 million from Ps. 185 million in 2016 to Ps. 449 million in 2017, primarily due to an increase in the services provided to Pemex Industrial Transformation. In 2017, our net loss related to our cogeneration and services activities increased by Ps. 57 million, from a net loss of Ps. 35 million in 2016 to a net loss of Ps. 92 million in 2017. This increase in loss was primarily due to an increase in costs and operating expenses as well as increased financing costs.

Fertilizers

In 2017, total sales related to the fertilizers segment decreased by Ps. 7 million, from Ps. 4,775 million in 2016 to Ps. 4,768 million in 2017. This decrease was primarily due to a decrease in the trade sales of ammonia. In 2017, our net loss related to our fertilizers activities increased by Ps. 2,611 million, from a net loss of Ps. 1,659 million in 2016 to a net loss of Ps. 4,270 million in 2017, primarily due to the net impairment of our fixed assets in this segment.

Ethylene

In 2017, total sales related to our ethylene segment decreased by Ps. 3,003 million, from Ps. 17,217 million in 2016 to Ps. 14,214 in 2017, primarily due to a decrease in sales of polyethylene, ethylene oxides, acrylonitrile and monoethylenglecol products. In 2017, our net income related to our ethylene activities decreased by Ps. 3,538 million, from a net income of Ps. 2,097 million in 2016 to a net loss of Ps. 1,442 in 2017. This decrease in income was primarily due a decrease in total sales.

Trading Companies

In 2017, total sales relating to the Trading Companies’ exports of crude oil and petroleum products to third parties (including services income) increased in peso terms, from Ps. 395,354 million in 2016 to Ps. 508,606 in 2017, primarily as a result of an increase in the prices of crude oil exports. In 2017, net income related to the Trading Companies increased by 7.9%, from Ps. 11,167 million in 2016 to Ps. 12,045 million in 2017, primarily due to an increase in the permanent investment in associates that was recognized at fair value.

Corporate and Other Subsidiary Companies

In 2017, the total sales relating to corporate and other subsidiary companies after inter-company eliminations increased from Ps. 1,209,045 million in 2016 to Ps. 1,524,600 million in 2017, primarily due to an increase in total intercompany sales as a result of an increase in the import of products. Net loss related to corporate and other subsidiary companies after inter-company eliminations decreased by Ps. 3,890 million, from a net loss of Ps. 76,809 million in 2016 to a net loss of Ps. 80,699 million in 2017, primarily due to unfavorable results from subsidiary companies and a loss in joint ventures and associates.

2016 Compared to 2015

Certain business units and assets that were operated by the refining, gas and basic petrochemicals and petrochemicals segments were transferred to our industrial transformation segment as a part of Pemex Industrial Transformation, on November 1, 2015. In order to provide investors with comparative information, we have consolidated 2015 results for these prior segments. Accordingly, in the case of our industrial transformation segment below, we present consolidated results for 2015 for the refining, gas and basic petrochemicals and petrochemicals segments under the heading “Industrial Transformation.” For more information on our corporate restructuring and our operating segments, see “Item 4— Information on the Company—History and Development—Energy Reform—Corporate Reorganization” and Note 1 to our consolidated financial statements included herein. For a detailed description of the financial results of each segment, see Note 5 to our consolidated financial statements included herein.

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Exploration and Production

In 2016, total intersegment sales, which include sales to our industrial transformation segment and the Trading Companies, decreased by 10.8%, primarily due to the decrease in crude oil export prices. As compared to 2015, our exploration and production segment’s sales of crude oil to the Trading Companies in 2016 decreased by 0.5% in peso terms and decreased by 16.2% in U.S. dollar terms, primarily due to a decrease in crude oil export prices. The weighted average price of crude oil sold by our exploration and production segment to the Trading Companies for export was U.S. $35.17 in 2016, as compared to U.S. $42.70 in 2015. Net loss related to exploration and production activities decreased by 91.3%, or Ps. 621,515 million, from a Ps. 667,394 million loss in 2015 to a Ps. 45,879 million loss in 2016, primarily due to a net reversal of impairment of our fixed assets in this segment.

Industrial Transformation

In 2016, trade sales related to industrial transformation activities decreased by 12.6%, from Ps. 747,739 million in 2015 to Ps. 653,654 million in 2016, primarily due to a decrease in the average sales prices of petroleum products. Intersegment sales decreased by 7.3%, from Ps. 126,264 million in 2015 to Ps. 117,096 million in 2016, primarily due to a decrease in the prices of petroleum products sold. In 2016, our net loss related to industrial transformation activities was Ps. 69,865 million, 19.9% lower than the loss of Ps. 87,209 million in 2015. The decrease in loss was primarily due to a net reversal of impairment of our fixed assets in this segment and a decrease in cost and operating expenses, which was partially offset by an increase in crude oil purchases and an increase in material acquisitions.

Drilling and Services

In 2016, total sales related to the drilling and services segment increased by 35.7%, from Ps. 1,512 million in 2015 to Ps. 2,052 million in 2016. This increase was primarily due to an increase in services provided to Pemex Exploration and Production. Net loss related to drilling and services increased by Ps. 597 million, from an income of Ps. 455 million in 2015 to a net loss of Ps. 142 million in 2016, primarily due to an increase in the expenses related to our intersegment services, an increase in the depreciation and maintenance required for our fixed assets, and a foreign exchange loss.

Logistics

In 2016, total sales related to the logistics segment increased by Ps. 60,176 million, from Ps. 10,955 million in 2015 to Ps. 71,131 million in 2016, primarily due to an increase in the services provided to Pemex Industrial Transformation. In 2016, our net loss related to logistics activities was Ps. 10,018 million, 171.9% higher than the loss of Ps. 3,685 million in 2015. The increase in net loss was primarily due to the transfer of certain of our assets to CENAGAS, higher operating expenses, an increase in financing cost, and a foreign exchange loss.

Fertilizers

In 2016, total sales related to the fertilizers segment increased by Ps. 3,071 million, from Ps. 1,705 million in 2015 to Ps. 4,776 million in 2016. This increase was primarily due to an increase in the trade sales of ammonia. In 2016, our net loss related to our fertilizers activities increased by Ps. 1,514 million, from a net loss of Ps. 145 million in 2015 to a net loss of Ps. 1,659 million in 2016, primarily due to costs related to the acquisition of Fertinal and an increase in the cost of services received from Pemex Logistics and from maritime freights.

Ethylene

In 2016, total sales related to our ethylene segment increased by Ps. 12,174 million, from Ps. 5,043 million in 2015 to Ps. 17,217 million in 2016, primarily due to an increase in the sales of polyethylene, ethylene oxides

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and monoethylenglecol products. In 2016, our net income related to our ethylene activities increased by Ps. 3,852 million, from a net loss of Ps. 1,755 million in 2015 to a net income of Ps. 2,097 million in 2016. This increase in income was primarily due to a net reversal of impairment of our plants and an increase in sales.

Trading Companies

In 2016, total sales relating to the Trading Companies’ exports of crude oil and petroleum products to third parties (including services income) decreased in peso terms, from Ps. 407,876 million in 2015 to Ps. 395,354 million in 2016, primarily as a result of a decrease in the prices of crude oil exports. In 2016, net income related to the Trading Companies increased by 28.4%, from Ps. 8,697 million in 2015 to Ps. 11,167 million, primarily due to an increase in the permanent investment in associates that was recognized at fair value.

Corporate and Other Subsidiary Companies

In 2016, the total sales relating to corporate and other subsidiary companies after inter-company eliminations increased from Ps. 1,183,143 million in 2015 to Ps. 1,209,045 million in 2016, primarily due to an increase in total intercompany sales as a result of an increase in the import of products. Net loss related to corporate and other subsidiary companies after inter-company eliminations increased by Ps. 115,335 million, from a net income of Ps. 38,526 million in 2015 to a net loss of Ps. 76,809 million in 2016, primarily due to unfavorable results from subsidiary companies, an increase in foreign exchange loss and an increase in financing costs.

Item 6. Directors, Senior Management and Employees

Under the Petróleos Mexicanos Law, Petróleos Mexicanos is governed by a ten-member Board of Directors composed as follows:

• the Secretary of Energy, who serves as the Chairperson and has the right to cast a tie-breaking vote;

• the Secretary of Finance and Public Credit;

• three Mexican Government representatives, who are appointed by the President of Mexico; and

• five independent members, who are appointed by the President of Mexico, subject to ratification by the Senate. Independent members perform their duties on a part-time basis, are not public officials (i.e., individuals holding federal, state or municipal government positions in Mexico) and have not been employed by Petróleos Mexicanos or any of the subsidiary entities during the two years prior to their appointment.

The Petróleos Mexicanos Law authorizes only the Secretary of Energy and the Secretary of Finance and Public Credit to designate an alternate to serve in his or her place, provided that the alternate is a public official at the undersecretary level, at minimum. This alternate may attend meetings of the Board of Directors of Petróleos Mexicanos and otherwise assume the duties of the director, except that the Chairperson’s designated alternate may not cast a tie-breaking vote. In addition, any ministry-level secretary serving as a member of the Board of Directors of Petróleos Mexicanos may designate an alternate to attend meetings on his or her behalf, provided that such alternate is a public official at the undersecretary level, at minimum.

Under the Petróleos Mexicanos Law, all public officials serving as members of the Board of Directors of Petróleos Mexicanos are required to act impartially and for the benefit and in the best interests of Petróleos Mexicanos, separating at all times the interests of the ministry or governmental entity for which they work from their duties as members of the Board of Directors.

177

Except in the case of the independent members first appointed under the Petróleos Mexicanos Law, the five independent members will be appointed to staggered five-year terms, and may be appointed for an additional term of the same length. The remaining members of the Board of Directors of Petróleos Mexicanos are not appointed for a specific term.

In 2014, the following individuals were appointed to serve as independent members of the Board of Directors of Petróleos Mexicanos for the initial terms set forth below:

• Mr. Alberto Tiburcio Celorio, for two years;

• Mr. Octavio Francisco Pastrana Pastrana, for three years;

• Mr. Jorge José Borja Navarrete, for four years;

• Mr. Jaime Lomelín Guillén, for five years; and

• Mr. Carlos Elizondo Mayer-Serra, for six years.

On February 17, 2015, Mr. Jaime Lomelín Guillén resigned from his position as independent member of the Board of Directors of Petróleos Mexicanos. On April 29, 2016, the Senate ratified the appointment of Mr. Felipe Duarte Olvera as an independent member to serve for the remainder of Mr. Lomelín Guillén’s term.

Under the Petróleos Mexicanos Law, each of the boards of directors of the subsidiary entities will consist of not less than five and no more than seven members. The majority of the members of each of the board of directors shall be appointed by and represent the Board of Directors of Petróleos Mexicanos. The Ministry of Energy and the Ministry of Finance and Public Credit may also appoint members to each board of directors of the subsidiary entities, subject to approval by the Board of Directors of Petróleos Mexicanos.

On November 17, 2017, the Board of Directors of Petróleos Mexicanos approved the Estatuto Orgánico (Organic Statute) of Petróleos Mexicanos, which was published in the Official Gazette of the Federation on December 5, 2017 and became effective the following day. This Organic Statute establishes the structure, organizational basis and functions of the administrative units of Petróleos Mexicanos and also delineates the duties and internal regulations of its Board of Directors.

178

The following tables set forth certain information with respect to directors and executive officers of Petróleos Mexicanos and each of the subsidiary entities as of April 30, 2018.

Petróleos Mexicanos—Directors and Executive Officers

Name	Position with Petróleos Mexicanos	Year Appointed
Mr. Pedro Joaquín Coldwell	Chairman of the Board of Directors of Petróleos Mexicanos and Secretary of Energy Born: 1950 Business experience: Chairman of the National Executive Committee of the PRI; Senator of the LXth and LXIst Legislatures; and Chairman of the National Executive Commission of Internal Procedures of the PRI. Other board memberships: Chairman of CFE; Chairman of the Centro Nacional de Control de Energía; Chairman of CENAGAS; Banco Nacional de Comercio Exterior, S.N.C., Institución de Banca de Desarrollo; Nacional Financiera, S.N.C., Institución de Banca de Desarrollo; Comisión Nacional de Vivienda; and Instituto Nacional de Ecología y Cambio Climático.	2012
Mr. Fernando Zendejas Reyes	Alternate Board Member of Petróleos Mexicanos and Undersecretary of Electricity of the Ministry of Energy Born: 1986 Business experience: Chief of the Legal Affairs Unit of the Ministry of Energy: Director General of Coordination of the Secretary of Energy´s Office; and Technical Secretary of the National Executive Committee of PRI. Other board memberships: Centro Nacional de Control de Energía; CENAGAS (Alternate); Comisión Nacional de Vivienda (Alternate); Comité de Estrategias e Inversiones of CFE (Alternate); Comité Ejecutivo de Crédito of Nacional Financiera, S.N.C., Institución de Banca de Desarrollo; Comité Ejecutivo de Crédito of Banco Nacional de Comercio Exterior, S.N.C., Institución de Banca de Desarrollo; Instituto Nacional de Investigaciones Nucleares; Entidad Mexicana de Acreditación; Comisión Nacional de Zonas Áridas; and Centro Nacional de Metrología.	2017

179

Petróleos Mexicanos—Directors and Executive Officers

Name	Position with Petróleos Mexicanos	Year Appointed
Mr. Ildefonso Guajardo Villarreal	Board Member of Petróleos Mexicanos and Secretary of Economy Born: 1957 Business experience: Deputy Coordinator of Political Economy for the President Elect’s Transition Team; Transition Coordinator to the PRI Candidate’s Presidential Campaign; and Federal Deputy of the LXIst Legislature. Other board memberships: Aeropuertos y Servicios Auxiliares; Banco del Ahorro Nacional y Servicios Financieros, S.N.C., Institución de Banca de Desarrollo; Banco Nacional de Comercio Exterior, S.N.C.; Caminos y Puentes Federales de Ingresos y Servicios Conexos; Centro de Investigación y Docencia Económicas, A.C.; Centro Nacional de Metrología; Centro Nacional de Gas Natural; Comisión Coordinadora para la Negociación de Precios de Medicamentos y otros Insumos para la Salud; CFE; Chairman of the Comisión Federal de Mejora Regulatoria; Comisión Intersecretarial de Bioseguridad de los Organismos Genéticamente Modificados; Comisión Intersecretarial de Cambio Climático; Chairman of the Comisión Intersecretarial de Compras y Obras de la Administración Pública Federal a la Micro, Pequeña y Mediana Empresa; Comisión Intersecretarial de Desarrollo Social; Comisión Intersecretarial de Gasto Público Financiamiento y Desincorporación; Comisión Intersecretarial de Precios y Tarifas de los Bienes y Servicios de la Administración Pública Federal; Comisión Intersecretarial de Vivienda; Comisión Intersecretarial para Asuntos de la Frontera Norte; Comisión Intersecretarial para el Desarrollo de los Bioenergéticos; Comisión Intersecretarial para el Desarrollo del Gobierno Electrónico; Comisión Intersecretarial para el Desarrollo Rural Sustentable; Comisión Intersecretarial para el Manejo Sustentable de Mares y Costas; Comisión Intersecretarial para la Coordinación Operativa en los Puntos de Internación al Territorio Nacional; Comisión Intersecretarial para la Atención de Sequias e Inundaciones; Comisión Intersecretarial para la Instrumentación de la Cruzada contra el Hambre; Comisión Intersecretarial para la Prevención y Combate a la Economía Ilegal; Comisión	2013

180

Petróleos Mexicanos—Directors and Executive Officers

Name	Position with Petróleos Mexicanos	Year Appointed
	Intersecretarial para la Prevención y Erradicación del Trabajo Infantil y la Protección de Adolescentes Trabajadores en Edad Permitida en México; Comisión Intersecretarial para la Transición Digital; Comisión Intersecretarial para la Prevención Social de la Violencia y la Delincuencia; Comisión Intersecretarial de Zonas Económicas Especiales; Chairman of the Comisión Nacional de Inversiones Extranjeras; Comisión Nacional de Vivienda; CONAGUA; Comisión Nacional Forestal; Comisión Nacional para el Conocimiento y Uso de la Biodiversidad; Comisión Nacional para el Desarrollo de los Pueblos Indígenas; Chairman of the Comité de Control y Desempeño Institucional; Chairman of the Comité Intersectorial para la Innovación; Comité Nacional de Productividad; Comité Nacional para el Desarrollo Sustentable de la Caña de Azúcar; Consejo Consultivo Empresarial para el Crecimiento Económico de México; Chairman of the Consejo Consultivo para el Fomento a la Industria Eléctrica Nacional; Consejo Consultivo de Turismo; Comisión Intersecretarial para el Sector Turístico; Consejo Nacional de Normalización y Certificación de Competencias Laborales; Consejo Mexicano para el Desarrollo Rural Sustentable; Consejo Nacional contra las Adicciones; Consejo Nacional de Ciencia y Tecnología; Consejo General de Investigación Científica, Desarrollo Tecnológico e Innovación; Consejo Nacional de Fomento Educativo; Consejo Nacional de Infraestructura; Consejo Nacional de Protección Civil; Consejo de Salubridad General; Consejo Nacional de Vivienda; Chairman of the Consejo Nacional para la Competitividad de la Micro, Pequeña y Mediana Empresa; Consejo Nacional para la Prevención y Control de las Enfermedades Crónicas no Transmisibles; Coordinación Nacional de Prospera, Programa de Inclusión Social; Consejo Nacional para las Comunidades Mexicanas en el Exterior; El Colegio de la Frontera Norte, A.C.; Chairman of the Fideicomiso de Fomento Minero; Fideicomiso del Fondo Institucional para el Fomento de la Ciencia, el Fomento de la Tecnología y el Fomento, Desarrollo y Consolidación de

181

Petróleos Mexicanos—Directors and Executive Officers

Name	Position with Petróleos Mexicanos	Year Appointed
	Científicos y Tecnólogos; Fideicomiso e-México; Chairman of the Fideicomiso para Promover el Acceso al Financiamiento de MIPYMES y Emprendedores (México Emprende); Chairman of the Fondo de Innovación Tecnológica SE-CONACYT; Gabinete Especializado de México Próspero; Gabinete Especializado de México con Responsabilidad Global; Gabinete Especializado Incluyente; Instituto del Fondo Nacional de la Vivienda de los Trabajadores; Instituto del Fondo Nacional para el Consumo de los Trabajadores; Instituto Mexicano de la Juventud; Chairman of the Instituto Mexicano de la Propiedad Industrial; Instituto Nacional de la Infraestructura Física Educativa; Instituto Nacional de las Mujeres; Chairman of the Instituto Nacional del Emprendedor; Nacional Financiera, S.N.C.; Chairman of the Fideicomiso Público ProMéxico; Chairman of the Servicio Geológico Mexicano; Servicio Nacional de Capacitación y Asistencia Técnica Rural; Servicio Postal Mexicano; Sistema de Investigación Alfonso Reyes; Sistema de Investigación Benito Juárez; Sistema de Investigación Francisco Villa; Sistema de Investigación Golfo de México; Sistema de Investigación Ignacio Zaragoza; Sistema de Investigación José María Morelos; Sistema de Investigación Justo Sierra; Sistema de Investigación Mar de Cortés; Sistema de Investigación Miguel Hidalgo; and Telecomunicaciones de México.
Mr. José Rogelio Garza Garza	Alternate Board Member of Petróleos Mexicanos and Undersecretary of Industry and Trade of the Ministry of Economy Born: 1971 Business experience: Cámara Nacional de la Industria Electrónica de Telecomunicaciones y Tecnologías de la Información; Secretary of the Ministry of Trade and Industrial Promotion; and Quality Coordinator of ISO-9002 Program of the Ministry of Trade and Industrial Promotion. Other board memberships: Instituto del Fondo Nacional de la Vivienda para los Trabajadores (Alternate).	2014

182

Petróleos Mexicanos—Directors and Executive Officers

Name	Position with Petróleos Mexicanos	Year Appointed
Mr. Aldo Ricardo Flores Quiroga	Board Member of Petróleos Mexicanos and Undersecretary of Hydrocarbons of the Ministry of Energy Born: 1967 Business experience: Secretary-General of the International Energy Forum; Director General of International Affairs of the Ministry of Energy; and Director General of Bilateral Economic Relations of the Ministry of Foreign Affairs. Other board memberships: CENAGAS; Consejo de Coordinación del Sector Energético; and Fondo Mexicano del Petróleo para la Estabilización y el Desarrollo (Alternate).	2016
Mr. José Antonio González Anaya	Board Member of Petróleos Mexicanos and Secretary of Finance and Public Credit Born: 1967 Business experience: Chief Executive Officer of Petróleos Mexicanos; Chief Executive Officer of the Instituto Mexicano del Seguro Social; and Undersecretary of Income of the Ministry of Finance and Public Credit. Other board memberships: Aeropuertos y Servicios Auxiliares; Caminos y Puentes Federales de Ingresos y Servicios Conexos; Chairman of Casa de Moneda de México; Chairman of Financiera Nacional de Desarrollo Agropecuario, Rural, Forestal y Pesquero; Fondo de Cultura Económica; Instituto del Fondo Nacional de la Vivienda para los Trabajadores; Instituto del Fondo Nacional para el Consumo de los Trabajadores; Instituto Mexicano de la Radio; Chairman of the Instituto para la Protección al Ahorro Bancario; Chairman of Lotería Nacional para la Asistencia Pública; Chairman of Pronósticos para la Asistencia Pública; Servicio Postal Mexicano; Telecomunicaciones de México; Chairman of Servicio de Administración y Enajenación de Bienes; ; Chairman of Agroasemex, S.A., Institución Nacional de Seguros; Chairman of Banco del Ahorro Nacional y Servicios Financieros, S.N.C., Institución de Banca de Desarrollo; Chairman of Banco Nacional de Comercio Exterior, S.N.C., Institución de Banca de Desarrollo; Chairman of Banco Nacional de Obras y Servicios Públicos, S.N.C., Institución de Banca de Desarrollo; Chairman of Banco Nacional del Ejército, Fuerza	2017

183

Petróleos Mexicanos—Directors and Executive Officers

Name	Position with Petróleos Mexicanos	Year Appointed
	Aérea y Armada, S.N.C., Institución de Banca de Desarrollo; Chairman of Nacional Financiera, S.N.C., Institución de Banca de Desarrollo; Chairman of Seguros de Crédito a la Vivienda SHF, S.A. de C.V.; Chairman of Sociedad Hipotecaria Federal, S.N.C., Institución de Banca de Desarrollo; CFE; Comisión de Estrategja e Inversiones of CFE; Comisión de Recursos Humanos y Remuneraciones of CFE; Fondo de Operación y Financiamiento Bancario a la Vivienda; CNBV; Comisión Nacional de Seguros y Fianzas; Chairman of the Comisión de Cambios; Comisión Nacional de Inversiones Extranjeras; Banco Interamericano de Desarrollo y Corporación Interamericana de Inversiones; Banco Internacional de Reconstrucción y Fomento del Banco Mundial; Organismo Multilateral de Garantía de Inversiones del Banco Mundial; and Banco de Desarrollo del Caribe.
Mr. Alberto Torres García	Alternate Board Member of Petróleos Mexicanos and Undersecretary of Income of the Ministry of Finance and Public Credit Born: 1971 Business experience: Head of the Public Credit Unit of the Ministry of Finance and Public Credit; Director General of Economic Research of Banco de México; and Director of Economic Studies of Banco de México. Other board memberships: Comisión Intersecretarial para el Desarrollo de los Bioenergéticos (Alternate); Comisión de Comercio Exterior; Comité Interinstitucional para la Aplicación del Estímulo Fiscal a Proyectos de Inversión en la Producción Teatral Nacional; Comité Interinstitucional para la Aplicación del Estímulo Fiscal a Proyectos de Inversión en la Producción Cinematográfica Nacional.	2018
Mr. Rafael Pacchiano Alamán	Board Member of Petróleos Mexicanos and Secretary of the Environmental and Natural Resources Born: 1975 Business experience: Undersecretary of Environmental Protection Management of the Ministry of Environment and Natural Resources; Youth Program Coordinator of the Transition	2015

184

Petróleos Mexicanos—Directors and Executive Officers

Name	Position with Petróleos Mexicanos	Year Appointed
	Team for the President-Elect of Mexico; and Federal Deputy in the LXI Legislature. Other board memberships: CFE; Salubridad General; Consejo Consultivo para las Energías Renovables; Consejo Nacional para la Competitividad de la Micro, Pequeña y Mediana Empresa; Comité Intersectorial para la Innovación; and Consejo Técnico de Servicio de Información Agroalimentaria y Pesquera.
Mr. Rodolfo Lacy Tamayo	Alternate Board Member of Petróleos Mexicanos and Undersecretary of Planning and Environmental Policies of the Ministry of the Environmental and Natural Resources Born: 1958 Business experience: Programs and Projects Coordinator of Centro Mario Molina para Estudios Estratégicos en Energía y Medio Ambiente; Executive Director of Special Projects of Colegio de Ingenieros Ambientales de México; and Chief of Staff of the Secretary of the Environmental and Natural Resources. Other board memberships: CFE (Alternate)	2015
Mr. Carlos Elizondo Mayer-Serra	Independent Board Member of Petróleos Mexicanos Born: 1962 Business experience: Assistant Professor at the Instituto Tecnológico y de Estudios Superiores de Monterrey, A.C.; Professor and Researcher at the Centro de Investigación y Docencia Económicas, A.C.; and Ambassador of Mexico to the Organización para la Cooperación y Desarrollo Económicos. Other board memberships: Corporación Interamericana de Entretenimiento, S.A.B. de C.V. (Independent) and Consejo Nacional de Ciencia y Tecnología.	2014
Mr. Octavio Francisco Pastrana Pastrana	Independent Board Member of Petróleos Mexicanos Born: 1952 Business experience: Partner of Administradora Ictineo Infraestructura, S.A.P.I. de C.V.; President and Chief Executive Officer of Isolux Mexico of Isolux Corsán, S.A.; and Director of Strategy and Business Development of ARB Arendal.	2014

185

Petróleos Mexicanos—Directors and Executive Officers

Name	Position with Petróleos Mexicanos	Year Appointed
	Other board memberships: COREMAR Empresa de Servicios Portuarios, S.A. and Grupo Aeroportuario de la Ciudad de México, S.A. de C.V. (Independent).
Mr. Jorge José Borja Navarrete	Independent Board Member of Petróleos Mexicanos Born: 1943 Business experience: Professional Member of the Board of Directors of Petróleos Mexicanos; Member of the Directive Board of the Universidad Nacional Autónoma de México; and Advisor to Grupo Xignux. Other board memberships: Grupo Aluminio, Vidrio y Construcción, S.A. de C.V	2014
Ms. María Teresa Fernández Labardini	Independent Board Member of Petróleos Mexicanos Born: 1967 Business experience: Partner of White & Case, S.C.; Executive Secretary-General Director of the Instituto para la Protección al Ahorro Bancario; General Technical Director of the CNBV; and Vice President of Regulation of the CNBV.	2017
Mr. Felipe Duarte Olvera	Independent Board Member of Petróleos Mexicanos Born: 1974 Business experience: Assistant Director General of Infrastructure and Energy of Grupo Financiero Banorte, S.A.B. de C.V.; Assistant Director General of Client Experience of Grupo Financiero Banorte, S.A.B. de C.V.; and Undersecretary of Transportation of the Ministry of Communications and Transportation. Other board memberships: Grupo Aeroportuario del Centro Norte, S.A.B. de C.V. (Independent)	2016
Mr. Carlos Alberto Treviño Medina	Chief Executive Officer/Director General Born: 1970 Business experience: Corporate Director of Management and Services of Petróleos Mexicanos; Chief Financial Officer of the Instituto Mexicano del Seguro Social; and Chief Executive Officer of Financiera Rural.	2017
Mr. David Ruelas Rodríguez	Chief Financial Officer / Corporate Director of Finance Born: 1977 Business experience: Deputy Director of Risk Management and Reinsurance of Petróleos	2018

186

Petróleos Mexicanos—Directors and Executive Officers

Name	Position with Petróleos Mexicanos	Year Appointed
	Mexicanos; Associate Managing Director of Corporate Financial Management of Petróleos Mexicanos; and Coordinator of Governmental Programs of Petróleos Mexicanos.
Mr. Marco Antonio Murillo Soberanis	Corporate Director of Management and Services Born: 1959 Business experience: Deputy Director of Labor Relations and Services for Personnel of Petróleos Mexicanos; Acting Corporate Director of Management of Petróleos Mexicanos; and Deputy Director of Human Resources of Petróleos Mexicanos.	2017
Mr. Rodulfo Figueroa Alonso	Corporate Director of Planning, Coordination and Performance Born: 1964 Business experience: Deputy Director of Planning of Pemex-Gas and Basic Petrochemicals; Associate Managing Director of Planning of Pemex-Gas and Basic Petrochemicals; and Associate Managing Director of Assessment and Information of Pemex-Gas and Basic Petrochemicals.	2015
Mr. Rodrigo Becerra Mizuno	Chief Information Officer/Corporate Director of Information Technology Born: 1975 Business experience: Director General of Public Sector (Asia Region) of Microsoft Corporation; Executive Director of Global Government of Microsoft Corporation; and Global Manager of Public Sector of Marketing Microsoft Corporation.	2016
Mr. Jorge Guillermo Lomelín Delgadillo	Acting Corporate Director of Alliances and New Businesses Born: 1975 Family Relationship: Married to Ms. Didier del Valle Toledo, Acting Director of Management of P.M.I. Comercio Internacional, S.A. de C.V. Business experience: Deputy Director of Industrial Transformation Business Development of Petróleos Mexicanos; Chief of Staff of the Corporate Director of Alliances and New Business of Petróleos Mexicanos; and Associate Managing Director of Administration Control of Petróleos Mexicanos.	2018

187

Petróleos Mexicanos—Directors and Executive Officers

Name	Position with Petróleos Mexicanos	Year Appointed
Mr. Jorge Eduardo Kim Villatoro	Legal Director Born: 1979 Business experience: Legal Director of the Instituto Mexicano del Seguro Social; Head of the Legislative Tax Unit of the Ministry of Finance and Public Credit; and Director General of Protection against Administrative Acts of the Procuraduría Fiscal de la Federación.	2016
Mr. José Salvador de la Mora Real	Head of the Institutional Internal Control Unit Born: 1959 Business experience: Operative Secretary of Information Technologies and Communications of the Tribunal Federal de Justicia Administrativa; Head of the Internal Control Body in Financiera Nacional para el Desarrollo Agropecuario, Rural, Forestal y Pesquero; and Associate Managing Director of Planning and Project Management of Petróleos Mexicanos.	2018
Mr. Luis Bartolini Esparza	Head of Internal Auditing Born: 1970 Business experience: Head of the Internal Control Unit of Nacional Financiera, S.N.C., Institución de Banca de Desarrollo; Director General of Career Services of Procuraduría General de la República; and Executive Director of Movable Assets of the Servicio de Administración y Enajenación de Bienes. Other board memberships: La Universidad La Salle Nezahualcóyotl.	2017

Pemex Exploration and Production—Directors and Executive Officers

Name	Position with Pemex Exploration and Production	Year Appointed
Mr. Carlos Alberto Treviño Medina	Chairman of the Board of Pemex Exploration and Production (refer to Petróleos Mexicanos)	2017
Mr. Claudio César de la Cerda Negrete	Board Member of Pemex Exploration and Production and Director General of Exploration and Extraction of Hydrocarbons of the Ministry of Energy Born: 1974 Business experience: Assistant General Director of Investment Promotion and Liaison of the Ministry of Energy; Vice-president of Operations and Business Development of Jaguar Exploración y Producción de Hidrocarburos, S.A.P.I de C.V.; and Vice-president of Geosciences and	2017

188

Pemex Exploration and Production—Directors and Executive Officers

Name	Position with Pemex Exploration and Production	Year Appointed
	Engineering and Director of Technology of Dowell Schlumberger de México, S.A. de C.V.
Mr. Alberto Torres García	Board Member of Pemex Exploration and Production (refer to Petróleos Mexicanos)	2018
Mr. David Ruelas Rodríguez	Board Member of Pemex Exploration and Production (refer to Petróleos Mexicanos)	2018
Mr. Carlos Rafael Murrieta Cummings	Board Member of Pemex Exploration and Production and Director General of Pemex Industrial Transformation Born: 1965 Business experience: Independent Business Consultant of Sendero; Corporate Director of Operations of Petroleos Mexicanos and Director of McKinsey & Co.	2016
Mr. Miguel Ángel Servín Diago	Board Member of Pemex Exploration and Production and Operative Director of Procurement and Supply of Petroleos Mexicanos Born: 1969 Business experience: Head of the Administrative Unit of the Instituto Mexicano del Seguro Social; Director General of Material Resources of the Ministry of Communications and Transportation; and Advisor of the Secretary of Communications and Transportation.	2016
Mr. J. Javier Hinojosa Puebla	Board Member of Pemex Exploration and Production and Director General of Pemex Exploration and Production Born: 1958 Business experience: Executive Director of Pemex Exploration and Production; Director of Development and Production of Pemex Exploration and Production; and Chief of Staff of the Director General of Pemex-Exploration and Production.	2015

189

Pemex Industrial Transformation—Directors and Executive Officers

Name	Position with Pemex Industrial Transformation	Year Appointed
Mr. Carlos Alberto Treviño Medina	Chairman of the Board of Pemex Industrial Transformation (refer to Petróleos Mexicanos)	2017
Mr. Marco Antonio Murillo Soberanis	Board Member of Pemex Industrial Transformation (refer to Petróleos Mexicanos)	2017
Mr. David Eduardo Rosales Hernández	Board Member of Pemex Industrial Transformation and Director General of Natural Gas and Petrochemicals of the Ministry of Energy Born: 1981 Business experience: Associate Managing Director of Regulations and Permits of Infraestructura Energética Nova, S.A.B. de C.V.; Deputy Director of Energy Projects of Banco Nacional de Obras y Servicios Públicos, S.N.C.; and Director of Transportation of the Regulatory Energy Commission.	2017
Mr. Alberto Torres García	Board Member of Pemex Industrial Transformation (refer to Petróleos Mexicanos)	2018
Mr. David Ruelas Rodríguez	Board Member of Pemex Industrial Transformation (refer to Petróleos Mexicanos)	2018
Mr. J. Javier Hinojosa Puebla	Board Member of Pemex Industrial Transformation (refer to Pemex Exploration and Production)	2015
Mr. Carlos Rafael Murrieta Cummings	Board Member of Pemex Industrial Transformation and Director General of Pemex Industrial Transformation (refer to Pemex Exploration and Production)	2016

190

Pemex Cogeneration and Services—Directors and Executive Officers

Name	Position with Cogeneration and Services	Year Appointed
Mr. Carlos Alberto Treviño Medina	Chairman of the Board of Pemex Cogeneration and Services (refer to Petróleos Mexicanos)	2017
Mr. Rodulfo Figueroa Alonso	Board Member of Pemex Cogeneration and Services (refer to Petróleos Mexicanos)	2015
Mr. Leonardo Cornejo Serrano	Board Member of Pemex Cogeneration and Services and Deputy Director of Industrial Projects of Pemex Industrial Transformation Born: 1969 Business experience: Director of Projects of Pemex Industrial Transformation; Deputy Director of Projects of Pemex-Refining; and Coordinator of Modernization and Capacity Expansion Projects of Pemex-Refining.	2016
Mr. David Ruelas Rodríguez	Board Member of Pemex Cogeneration and Services (refer to Petróleos Mexicanos)	2018
Mr. José Salvador de la Mora Real	Board Member of Pemex Cogeneration and Services (refer to Petróleos Mexicanos)	2018
Mr. Jorge Lomelín Delgadillo	Board Member of Pemex Cogeneration and Services (refer to Petróleos Mexicanos)	2018
Ms. Raquel Buenrostro Sánchez .	Acting Director General of Pemex Cogeneration and Services and Associate Managing Director of Planning and Development of Pemex Cogeneration and Services Born: 1970 Business experience: Associate Managing Director of Planning of Grupo Adya Select, S. de R.L. de C.V.; Advisor to the Director of Management and Finance of PMI; and Director General of Management of Secretaría de Turismo.	2017

191

Pemex Drilling and Services—Directors and Executive Officers

Name	Position with Pemex Drilling and Services	Year Appointed
Mr. Carlos Alberto Treviño Medina	Chairman of the Board of Pemex Drilling and Services (refer to Petróleos Mexicanos)	2017
Mr. Rodulfo Figueroa Alonso	Board Member of Pemex Drilling and Services (refer to Petróleos Mexicanos)	2016
Mr. Marco Antonio Murillo Soberanis	Board Member of Pemex Drilling and Services (refer to Petróleos Mexicanos)	2017
Mr. Rodrigo Becerra Mizuno	Board Member of Pemex Drilling and Services (refer to Petróleos Mexicanos)	2016
Mr. J. Javier Hinojosa Puebla	Board Member of Pemex Drilling and Services (refer to Pemex Exploration and Production)	2015
Mr. Jorge Valadez Montoya	Board Member of Pemex Drilling and Services and Acting Deputy Director of Businesses Development of Exploration and Production of Petróleos Mexicanos Born: 1973 Business experience: Associate Managing Director of Alliances and New Businesses for Production Support of Petróleos Mexicanos; Deputy Director of Project Analysis of PMI; and Project Leader of Petróleos Mexicanos.	2017
Mr. Miguel Ángel Lugo Valdez	Board Member of Pemex Drilling and Services and Coordinator of Procurement and Supply for Exploration and Production of Petróleos Mexicanos Born: 1967 Business experience: Acting Deputy Director of Strategy Management and Business Model Support of Petróleos Mexicanos; Acting Associate Managing Director of Contract Planning, Evaluation and Consolidation of Petróleos Mexicanos; and Acting Associate Managing Director of Exploration and Production Contracts of Petróleos Mexicanos.	2016
Mr. Guillermo Edmundo Bernal Miranda	Director General of Pemex Drilling and Services Born: 1957 Business experience: Secretary of Finance and Management of the Government of the State of Puebla; Political and Educational Affairs Minister of the Consulate of Mexico in San Francisco, California in the United States of America; General Coordinator of Popular Finances of Instituto Nacional para la Economía Social.	2017

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Pemex Logistics—Directors and Executive Officers

Name	Position with Pemex Logistics	Year Appointed
Mr. Carlos Alberto Treviño Medina	Chairman of the Board of Pemex Logistics (refer to Petróleos Mexicanos)	2017
Mr. Marco Antonio Murillo Soberanis	Board Member of Pemex Logistics (refer to Petróleos Mexicanos)	2017
Mr. Rodrigo Becerra Mizuno	Board Member of Pemex Logistics (refer to Petróleos Mexicanos)	2016
Ms. Guadalupe Merino Bañuelos	Board Member of Pemex Logistics and Deputy Director of Strategic Planning and Regulatory Analysis of Petróleos Mexicanos Born: 1971 Business experience: Associate Managing Director of Strategic Planning of Petróleos Mexicanos; Deputy Director of Programming and Budgeting of Petróleos Mexicanos; and Deputy Director of Corporate Services of Petroóleos Mexicanos.	2016
Mr. Enrique Cházaro Acosta	Board Member of Pemex Logistics and Deputy Director of Budget of Petróleos Mexicanos Born: 1988 Business experience: Executive Coordinator of the Director of Management and Services of Petróleos Mexicanos; Regulatory Coordinator of the Economic and Social Benefits Director of the Instituto Mexicano del Seguro Socia; and Advisor to the Director General of Instituto Mexicano del Seguro Social.	2017
Mr. José Luis Antonio Gómez Góngora	Board Member of Pemex Logistics and Coordinator of Procurement and Supply for Industrial Transformation of Petroleos Mexicanos Born: 1957 Business experience: Associate Managing Director of Contracts for Gas and Basic Petrochemicals of Petróleos Mexicanos; Associate Managing Director of Material Resources of Pemex-Gas and Basic Petrochemicals; and Head of the Management Unit of Petróleos Mexicanos.	2015

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Pemex Logistics—Directors and Executive Officers

Name	Position with Pemex Logistics	Year Appointed
Mr. Antonio Lopez Velarde Loera	Board Member of Pemex Logistics and Deputy Director of Risk Management and Reinsurance of Petróleos Mexicanos Born: 1976 Business experience: Associate Managing Director of Financial Risk Management of Petróleos Mexicanos; Deputy Manager of Capital Markets and Derivatives of Petróleos Mexicanos; and Deputy Manager of Derivative Transactions of Petróleos Mexicanos.	2018
Mr. Armando David Palacios Hernández	Director General Born: 1973 Business experience: Corporate Director of Alliances and New Businesses of Petróleos Mexicanos; Director of Management of Instituto Mexicano del Seguro Social; and Director of Economic and Social Benefits of Instituto Mexicano del Seguro Social. Other board memberships: Deer Park Refining Limited Partnership.	2018

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Pemex Fertilizers—Directors and Executive Officers

Name	Position with Pemex Fertilizers	Year Appointed
Mr. Carlos Alberto Treviño Medina	Chairman of the Board of Pemex Fertilizers (refer to Petróleos Mexicanos)	2017
Mr. Luis Rodolfo Capitanachi Dagdug	Board Member of Pemex Fertilizers and Associate Managing Director of Finance, Industrial Processes and Logistics of Petróleos Mexicanos Born: 1971 Business experience: Associate Managing Director of Accounting for Productive State-Owned Subsidiaries and Other Businesses of Petróleos Mexicanos; Acting Deputy Director of Management and Finance of Pemex-Petrochemicals; and Associate Managing Director of Financial Resources of Pemex-Petrochemicals.	2015
Ms. Alma Rosa Moreno Razo	Board Member of Pemex Fertilizers and Deputy Director of Economic-Financial Performance of Petróleos Mexicanos. Born: 1952 Business experience: Advisor to the Director General of Petróleos Mexicanos; Partner of ITG Consultores; and General Director of Management of Grupo Financiero Banorte, S.A.B. de C.V.	2015
Mr. Marco Antonio Murillo Soberanis	Board Member of Pemex Fertilizers (refer to Petróleos Mexicanos)	2017
Mr. Armando David Palacios Hernández	Board Member of Pemex Fertilizers (refer to Pemex Logistics)	2018
Mr. Jorge Collard de la Rocha	Board Member of Pemex Fertilizers Deputy Director of Business Performance of Petróleos Mexicanos Born: 1951 Business experience: Deputy Director of Management and Finance of Pemex-Petrochemicals; Deputy Director of Management and Finance of Pemex-Exploration and Production; and Acting Deputy Director of Supplies of Petróleos Mexicanos	2015
Mr. Juan Alfredo Lozano Tovar	Director General of Pemex Fertilizers Born: 1968 Business experience: Director of Economic and Social Benefits of the Instituto Mexicano del Seguro Social; General Secretary of the Conferencia Interamericana de Seguridad Social; and Head of the Liaisons of the Instituto Mexicano del Seguro Social.	2016

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Pemex Ethylene—Directors and Executive Officers

Name	Position with Pemex Ethylene	Year Appointed
Mr. Carlos Alberto Treviño Medina	Chairman of the Board of Pemex Ethylene (refer to Petróleos Mexicanos)	2017
Mr. Enrique Cházaro Acosta	Board Member of Pemex Ethylene (refer to Pemex Logistics)	2017
Mr. Jorge Valadez Montoya	Board Member of Pemex Ethylene (refer to Pemex Drilling and Services)	2015
Mr. Jorge Collard de la Rocha	Board Member of Pemex Ethylene (refer to Petróleos Mexicanos)	2015
Mr. José Luis Antonio Gómez Góngora	Board Member of Pemex Ethylene (refer to Pemex Logistics)	2015
Mr. Juan Alfredo Lozano Tovar	Board Member of Pemex Ethylene (refer to Pemex Fertilizers)	2016
Mr. José Manuel Alvarado Doria	Board Member of Pemex Ethylene and Deputy Director of Gas and Petrochemicals Process of Pemex Industrial Transformation Born: 1957 Business experience: Deputy Director of Production of Pemex-Gas and Basic Petrochemicals; Acting Associate Managing Director of Evaluation and Improvement of Pemex-Gas and Basic Petrochemicals; and Associate Managing Director of Operative Control, Optimization and Safety of Pemex-Gas and Basic Petrochemicals.	2016
Mr. Luis Rafael Montanaro Sánchez	Director General Born: 1969 Business experience: Deputy Director of Planning of Pemex Petrochemicals, Acting Deputy Director of Operations of Pemex Petrochemicals; and Associate Managing Director of Morelos PC of Pemex-Petrochemicals;. Other board memberships: Petroquímica Mexicana de Vinilo, S.A. de C.V.; PMV Minera, S.A. de C.V.; and PMV Servicios Administrativas, S.A. de C.V.	2016

Compensation of Directors and Officers

For the year ended December 31, 2017, the aggregate compensation of executive officers of Petróleos Mexicanos and the existing subsidiary entities (17 people) paid or accrued in that year for services in all capacities was approximately Ps. 50.7 million. Except in the case of the independent members, with respect to

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the previous Board of Directors of Petróleos Mexicanos and the boards of directors of the existing subsidiary entities, and the independent members, with respect to the new Board of Directors of Petróleos Mexicanos, the members of our boards of directors do not receive compensation for their services. The compensation paid or accrued during 2017 to the professional members of the previous Board of Directors of Petróleos Mexicanos and boards of directors of the existing subsidiary entities was approximately Ps. 7.5 million. See “Item 7—Major Shareholders and Related Party Transactions—Related Party Transactions” for information about the salary advances that we offer to our executive officers as an employee benefit.

Board Practices

Except in the case of the independent members with respect to the Board of Directors of Petróleos Mexicanos, neither the members of the boards of directors nor the executive officers of Petróleos Mexicanos or the productive state-owned subsidiaries are appointed for a specific term. The length of the terms of the Secretary of Energy and the Secretary of Finance and Public Credit is, however, limited by the length of their respective positions in the Mexican Government. Except in the case of the independent members first appointed under the Petróleos Mexicanos Law, the five independent members of the Board of Directors of Petróleos Mexicanos will be appointed for five-year terms, and may be appointed for an additional term of the same length.

The Mexican Government representatives that serve as members of the boards of directors of Petróleos Mexicanos and each of the existing subsidiary entities may be removed at the discretion of the President of Mexico. The independent members of the Board of Directors of Petróleos Mexicanos may be removed for cause, including failure to carry out the duties and obligations set forth in the Petróleos Mexicanos Law, by the President of Mexico upon Senate approval.

On October 14, 2014, the Board of Directors of Petróleos Mexicanos appointed members to and convened the four committees established by the Petróleos Mexicanos Law to support its work. Unless otherwise specified in the Petróleos Mexicanos Law, the memberships of these committees must consist of at least three, but no more than five, members of the Board of Directors of Petróleos Mexicanos. Each of these committees must include two independent members of the Board of Directors of Petróleos Mexicanos, with the exception of the Audit Committee, which must include three independent members. Each of the Secretary of Energy, the Secretary of Finance and Public Credit and any ministry-level secretary serving as a member of the Board of Directors of Petróleos Mexicanos may designate one or more alternates to take his or her place at committee meetings, provided that these alternates are public officials whose positions are not more than two levels below such secretary’s position in the Mexican Government.

The committees may authorize a representative of the Director General to attend their meetings as a guest with the right to participate, but not vote, when deemed advisable for the performance of their duties.

Audit Committee

The Audit Committee of the Board of Directors of Petróleos Mexicanos is required to, among other duties, oversee our management, evaluate our financial and operational performance, monitor the status of our internal control systems, as well as nominate our external auditors, whose appointments are approved by the Board of Directors of Petróleos Mexicanos. See “Item 16C—Principal Accountant Fees and Services.”

Each of the three members of the Audit Committee is “independent” of Petróleos Mexicanos within the meaning of Rule 10A-3 under the Securities Exchange Act of 1934, as amended (the Exchange Act). In accordance with the Petróleos Mexicanos Law, the Audit Committee consists of three independent members of the Board of Directors of Petróleos Mexicanos, each of whom will serve as the chair of the committee on a rotating, annual basis, as determined by the Board of Directors of Petróleos Mexicanos.

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The Audit Committee consists of the following members:

• Ms. María Teresa Fernández Labardini, independent member of the Board of Directors of Petróleos Mexicanos and Chairperson of the Audit Committee;

• Mr. Jorge José Borja Navarrete, independent member of the Board of Directors of Petróleos Mexicanos; and

• Mr. Felipe Duarte Olvera, independent member of the Board of Directors of Petróleos Mexicanos.

A representative of the Director General, the Head of the Internal Auditing Area, the Legal Director or any other person may attend the Audit Committee’s meetings as a guest with the right to participate, but not vote, when deemed advisable and appropriate given the subject matter to be discussed.

Human Resources and Compensation Committee

The Human Resources and Compensation Committee is chaired by an independent member of the Board of Directors of Petróleos Mexicanos and includes the Secretary of Finance and Public Credit as a permanent member. The duties of the Human Resources and Compensation Committee include, among others, proposing the compensation of the Director General and other members of senior management of Petróleos Mexicanos within three levels of the Director General, as well as proposing hiring policies, performance management guidelines and the compensation of all other employees of Petróleos Mexicanos.

The Human Resources and Compensation Committee of Petróleos Mexicanos consists of the following members:

• Mr. Carlos Elizondo Mayer-Serra, independent member of the Board of Directors of Petróleos Mexicanos and Chairperson of the Human Resources and Compensation Committee;

• Mr. Octavio Francisco Pastrana Pastrana, independent member of the Board of Directors of Petróleos Mexicanos;

• Mr. José Antonio González Anaya, member of the Board of Directors of Petróleos Mexicanos;

• Mr. Ildefonso Guajardo Villarreal, member of the Board of Directors of Petróleos Mexicanos; and

• Mr. Rafael Pacchiano Alamán, member of the Board of Directors of Petróleos Mexicanos.

Strategy and Investment Committee

The Strategy and Investment Committee is chaired by an independent member of the Board of Directors of Petróleos Mexicanos on a rotating annual basis and is required to, among other duties, analyze our business plan and assist the Board of Directors of Petróleos Mexicanos in the approval of guidelines, priorities and general policies related to investments made by Petróleos Mexicanos.

The Strategy and Investment Committee of Petróleos Mexicanos consists of the following members:

• Mr. Octavio Francisco Pastrana Pastrana, independent member of the Board of Directors of Petróleos Mexicanos and Chairperson of the Strategy and Investment Committee;

• Mr. Carlos Elizondo Mayer-Serra, independent member of the Board of Directors of Petróleos Mexicanos;

• Mr. Pedro Joaquín Coldwell, member of the Board of Directors of Petróleos Mexicanos;

• Mr. José Antonio González Anaya, member of the Board of Directors of Petróleos Mexicanos; and

• Mr. Ildefonso Guajardo Villarreal, member of the Board of Directors of Petróleos Mexicanos.

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Acquisitions, Leasing, Public Works and Services Committee

The Acquisitions, Leasing, Public Works and Services Committee is chaired by an independent member of the Board of Directors of Petróleos Mexicanos on a rotating annual basis and, among other duties, reviews, evaluates, monitors and develops recommendations regarding the annual programs of Petróleos Mexicanos for acquisition, construction and services contracts, and determines whether an exception to the public bidding process is applicable in specific cases.

The Acquisitions, Leasing, Public Works and Services Committee of Petróleos Mexicanos consists of the following members:

• Mr. Felipe Duarte Olvera, independent member of the Board of Directors of Petróleos Mexicanos and Chairperson of the Acquisitions, Leasing, Public Works and Services Committee;

• Mr. Jorge José Borja Navarrete, independent member of the Board of Directors of Petróleos Mexicanos;

• Mr. Pedro Joaquín Coldwell, member of the Board of Directors of Petróleos Mexicanos;

• Mr. José Antonio González Anaya, member of the Board of Directors of Petróleos Mexicanos; and

• Mr. Rafael Pacchiano Alamán, member of the Board of Directors of Petróleos Mexicanos.

Employees

Excluding employees employed by us on a temporary basis, at December 31, 2017, Petróleos Mexicanos, its subsidiary entities and subsidiary companies had 127,941 employees, as compared to 130,333 at December 31, 2016. During 2017, Petróleos Mexicanos and the productive state-owned subsidiaries employed an average of 7,298 temporary employees.

The following table sets forth our employee numbers for the five years ended December 31, 2017:

Year	Petróleos Mexicanos and Subsidiary Entities		Subsidiary Companies		Total
2013		154,474		764		155,538
2014		153,085		804		153,889
2015		138,397		786		139,183
2016		126,940		3,393		130,333
2017		124,660		3,281		127,941

Source: Petróleos Mexicanos and the subsidiary companies.

As of December 31, 2017, the Petroleum Workers’ Union represented approximately 81.2% of the work force of Petróleos Mexicanos and the productive state-owned subsidiaries. The members of the Petroleum Workers’ Union are PEMEX employees and they elect their own leadership from among their ranks. Our relationship with our employees is regulated by the Ley Federal de Trabajo (which we refer to as the Federal Labor Law), a collective bargaining agreement between Petróleos Mexicanos and the Petroleum Workers’ Union and the Employment Regulation for White Collar Employees of PEMEX and Subsidiary Entities. The collective bargaining agreement is subject to renegotiation every two years, although salaries are reviewed annually. Since the Petroleum Workers’ Union’s was officially established in 1938, we have not experienced labor strikes; we have experienced work stoppages for short periods of time, but none of these stoppages had a material adverse effect on our operations.

On July 11, 2017, Petróleos Mexicanos and the Petroleum Workers’ Union executed a new collective bargaining agreement that will regulate their labor relations until July 31, 2019. The new collective bargaining agreement provided for a 3.12% increase in wages.

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On November 11, 2015, Petróleos Mexicanos announced that it had signed an agreement with the Petroleum Workers’ Union to modify the pension regime applicable to current and new employees. Pursuant to the agreement, the retirement age for employees with less than 15 years of service has been increased from 55 to 60. Employees are still required to serve for at least 30 years in order to be eligible to receive full retirement benefits. In addition, new employees will receive individual defined contributions retirement plans, which will benefit from direct contributions from Petróleos Mexicanos, portability and tax benefits applicable to retirement savings. Current employees will also be permitted to opt into the new defined contributions retirement plans.

On December 18, 2015, the Director General of Petróleos Mexicanos informed the Ministry of Finance and Public Credit that our pension liabilities were expected to decrease by Ps. 186.5 billion as a result of the modifications to our pension regime described above. As of December 31, 2015, our pension liabilities had decreased by Ps. 196.0 billion.

On December 24, 2015, the Ministry of Finance and Public Credit published in the Official Gazette of the Federation the Disposiciones de carácter general relativas a la asunción por parte del Gobierno Federal de obligaciones de pago de pensiones y jubilaciones a cargo de Petróleos Mexicanos y sus empresas productivas subsidiarias (General provisions regarding the assumption by the Mexican Government of the payment obligations related to pensions and retirement plans of Petróleos Mexicanos and its productive state-owned subsidiaries). On August 3, 2016, the Ministry of Finance and Public Credit informed us that the Mexican Government would assume Ps. 184.2 billion in payment liabilities related to our pensions and retirement plans, and accordingly replaced the Ps. 50 billion promissory note issued to us on December 24, 2015 with Ps. 184.2 billion in promissory notes.

In accordance with the Federal Labor Law and collective bargaining agreement in effect as of December 31, 2015, Petróleos Mexicanos and the productive state-owned subsidiaries are under an obligation to pay seniority premiums to retiring employees and pensions to retired employees, as well as death benefits and pensions to certain survivors of retired employees. Retirees are entitled to receive increases in their pensions, of at least the increase in NCPI, whenever salary increases are granted to current employees. We also provide health and medical benefits to employees, retired employees and their beneficiaries and, subject to our overall budgetary constraints, we provide an interest-rate subsidy on employees’ mortgage loans.

On November 5, 1997, the Ministry of Finance and Public Credit and the Board of Directors of Petróleos Mexicanos authorized the formation of a trust called the Pemex Labor Fund. This fund is a vehicle to fund labor liabilities, current pension payments and seniority premiums. We have designed a contribution plan to increase the funds held in this trust and to continue to make payments on outstanding labor and pension liabilities. Our contributions to the plan assets for our retirement benefits totaled Ps. 55,693 million in 2016 and Ps. 51,952 million in 2017. As of December 31, 2016 and 2017, the balance of the Pemex Labor Fund was Ps. 9,490 million and Ps. 8,485 million, respectively.

Item 7. Major Shareholders and Related Party Transactions

Major Shareholders

Petróleos Mexicanos and the subsidiary entities have no shareholders because they are public entities of the Mexican Government. The Mexican Government controls us and incorporates the consolidated annual budget and financing program of Petróleos Mexicanos and the subsidiary entities into its budget, which must be approved by the Chamber of Deputies each year. Any adjustment proposed by the Board of Directors of Petróleos Mexicanos to change our annual financial balance goal or increase the limit on our wage and salary expenditures budget or our financing program must be approved by the Chamber of Deputies. See “Item 4—Information on the Company—General Regulatory Framework” for more information about the Mexican Government’s authority with respect to our budget. Our operations in the oil and gas sector are also regulated by the Mexican Government and its ministries.

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Mexican Government officials hold five of the ten seats on the Board of Directors of Petróleos Mexicanos, and the Secretary of Energy is the Chairperson of the Board of Directors of Petróleos Mexicanos with the power to cast a tie-breaking vote. An additional five seats on the Board of Directors are held by independent members appointed by the President of Mexico and ratified by the Senate. The Director General of Petróleos Mexicanos is a member of the President of Mexico’s cabinet. See also “Item 3—Key Information—Risk Factors—Risk Factors Related to our Relationship with the Mexican Government.”

Related Party Transactions

Directors and employees of Petróleos Mexicanos and the Subsidiary Entities are subject to regulations addressing conflicts of interest, including the Petróleos Mexicanos Law, Ley Federal de Responsabilidades Administrativas de los Servidores Públicos (Federal Law of Administrative Responsibilities of Public Officials) and the Políticas y Lineamientos Anticorrupción para Petróleos Mexicanos, sus Empresas Productivas Subsidiarias y, en su caso, Empresas Filiales (Anticorruption Policies and Guidelines for Petróleos Mexicanos, its Subsidiary Productive Companies and, where applicable, Subsidiary Companies). Under these provisions, directors and employees of Petróleos Mexicanos are obligated to “recuse themselves from intervening in any way in the attention to, processing or resolution of matters in which they might have personal, family or business interest, including those where some benefit can result for themselves, their spouse, blood or affinity relatives up to the fourth degree, or civil relatives, or for third parties with which they have professional, labor or business relations, or for partners or partnerships where the public officials or the persons referred above are or have been members thereof.”

The Board of Directors of Petróleos Mexicanos, including the independent members who are not public officials, are subject to the duties of loyalty and diligence. In accordance with the Petróleos Mexicanos Law, an independent member of the Board of Directors of Petróleos Mexicanos may be removed from his or her position for, among other causes: (1) utilizing for personal benefit or for the benefit of any third party the information made available to him or her in connection with the exercise of his or her duties as a board member; (2) disclosing such information in violation of applicable law; or (3) not recusing him or herself from discussion of and voting on matters in respect of which he or she has a conflict of interest. A member of the Board of Directors of Petróleos Mexicanos or of the board of directors of an existing subsidiary entity who acts in contravention of the Petróleos Mexicanos Law may be held liable for any damages that he or she caused to Petróleos Mexicanos or an existing subsidiary entity.

As an employee benefit, we offer salary advances to all of our eligible Petroleum Workers’ Union and non-union workers, including our executive officers, pursuant to the programs set forth in the collective bargaining agreement and in the Employment Regulation of White Collar Employees of Petróleos Mexicanos and Subsidiary Entities, respectively. The salary advances, which are non-interest bearing, are offered to each eligible employee in an amount up to a maximum of four months’ salary and are repaid through salary deductions in equal installments over a period of either one or two years, as elected by the employee. Most of our employees take advantage of this benefit. The largest amount of salary advances outstanding to executive officers at any one time during 2017 was Ps. 4.5 million. As of March 31, 2018, the aggregate amount of salary advances outstanding to our executive officers was Ps. 2.4 million.

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Secretary of Energy, Mr. Pedro Joaquín Coldwell, Chairman of the Board of Directors of Petróleos Mexicanos since December 2012, as well as certain members of his family, have held ownership interests since prior to Mr. Pedro Joaquín Coldwell’s appointment to the Board of Directors and through October of 2017 in companies that have entered into agreements with Pemex-Refining, now held by Pemex Industrial Transformation, for the sale and purchase of gasoline and other products by certain retail service stations and a wholesale distributor, as well as the performance of other related activities, as provided below:

Company	Name	Ownership Share
Servicio Cozumel, S.A. de C.V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1) Mr. Pedro Oscar Joaquín Delbouis (son of Mr. Joaquín Coldwell) Mr. Nassim Joaquín Delbouis (son of Mr. Joaquín Coldwell)	60% 20% 20%
Planta de Combustible Cozumel, S.A. de C.V. (which operates as a wholesale distributor)	Testamentary Trust(2) Mr. Pedro Joaquín Coldwell(1)	57% 40%
Gasolinera y Servicios Juárez, S.A. de C.V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1) Mr. Ignacio Nassim Ruiz Joaquín (nephew of Mr. Joaquín Coldwell) Testamentary Trust(3)	40% 20% 40%
Combustibles Caleta, S.A. de C.V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1) Mr. Pedro Oscar Joaquín Delbouis Mr. Nassim Joaquín Delbouis Mr. Ignacio Nassim Ruiz Joaquín Testamentary Trust(4)	20% 20% 20% 20% 20%
Combustibles San Miguel, S.A. de C.V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1) Mr. Pedro Oscar Joaquín Delbouis Mr. Nassim Joaquín Delbouis Mr. Ignacio Nassim Ruiz Joaquín	25% 25% 25% 25%

(1) In Novermber 2017, Mr. Pedro Joaquín Coldwell transmitted all of his shares in these companies to a management and investment trust held at the Banco Mercantil del Norte, S.A, Institución de Banca Múltiple, Grupo Financiero Banorte.

(2) 60% of these shares were owned by Fausto Nassim Joaquín Ibarra (father of Pedro Joaquín Coldwell), until his death in June of 2016, after which 57% of these shares became property of an investment, management and testamentary revocable trust, which we refer to as the Testamentary Trust. 50% of the voting rights of these shares are currently exercised by Mr. Pedro Oscar Joaquín Delbouis, and 50% are exercised by Mr. Nassim Joaquín Delbouis.

(3) 40% of these shares were owned by Fausto Nassim Joaquín Ibarra until his death in June of 2016, after which these shares became property of the Testamentary Trust. 100% of the voting rights of these shares are currently exercised by Mr. Pedro Joaquín Coldwell.

(4) 20% of these shares were owned by Fausto Nassim Joaquín Ibarra until his death in June of 2016, after which these shares became property of the Testamentary Trust. 50% of the voting rights of these shares are currently exercised by Mr. Pedro Oscar Joaquín Delbouis, and 50% are exercised by Mr. Nassim Joaquín Delbouis.

The rights of these companies to operate retail service stations and distribute gasoline and other products on a wholesale basis in Mexico are dependent on these agreements, the expiration or non-renewal of which may adversely affect their business. These agreements are based on our standard forms of agreements and contain the standard terms and conditions applicable to all of Pemex Industrial Transformation retail service stations and wholesale distributors.

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Item 8. Financial Information

Consolidated Statements and Other Financial Information

See Item 18. “Financial Statements”.

Legal Proceedings

Labor-Related Proceedings

We are a party to various legal actions involving labor claims of former and present employees. These labor disputes relate to severance payments, life insurance benefits, extensions of labor contracts, level of wages, improper termination and employee housing. We do not expect these lawsuits to have a material adverse effect on our financial condition or future results of operations.

For information on our negotiations with the Petroleum Workers’ Union and collective bargaining agreements, see “Item 6—Directors, Senior Management and Employees—Employees.”

Audits and Other Investigations by the Mexican Government

The Auditoría Superior de la Federación (Superior Audit Office of the Federation, or the ASF), annually reviews the Cuenta Pública (Public Account) of Mexican Government entities, including Petróleos Mexicanos and our subsidiary entities. This review focuses mainly on the entities’ compliance with budgetary benchmarks and budget and accounting laws. The ASF prepares reports of its observations based on this review. The reports are subject to our analysis and, if necessary, our clarification and explanation of any issues raised during the audit. Discrepancies in amounts spent may subject our officials to legal sanctions. However, in most instances, any observed issues are clarified and disposed of.

The Liabilities Unit at Petróleos Mexicanos, which is part of the SFP, is responsible for receiving complaints and investigating violations of the Federal Law of Administrative Responsibilities of Public Officials and the General Law of Administrative Liabilities, as well as imposing administrative penalties in accordance with the law. The SFP, through the Liabilities Unit, provided us with the information below regarding the main investigations and administrative proceedings against our employees and former employees.

In March and April 2010, the SFP imposed administrative penalties against several officers of Pemex-Refining in connection with a pipeline rupture in Nanchital, Veracruz. As of the date of this report, the final outstanding appeal was denied, the penalties were confirmed and all legal proceedings related to these matters have concluded.

In May 2010, the SFP filed a criminal complaint and initiated two administrative proceedings against María Karen Miyazaki Hara, who served as PMI’s Deputy Director of Trading of Intermediate Distillates, for allegedly committing acts of corruption pursuant to which PMI lost revenues of approximately U.S. $13 million. The alleged acts involved the unauthorized sale of ULSD for the economic benefit of foreign companies, including Blue Oil Trading Ltd. On November 25, 2015, the SFP was notified by the Federal Attorney General that there would be no criminal prosecution based on a resolution issued on October 6, 2015. As of the date of this annual report, the criminal complaint has been concluded. In November 2010, the first administrative proceedings concluded, resulting in Ms. Miyazaki Hara being fined Ps. 164.2 million and banned from holding public sector positions for 20 years. Ms. Miyazaki Hara filed a motion before the Séptima Sala Regional Metropolitana (Seventh Regional Metropolitan Court) of the Federal Court of Tax and Administrative Justice seeking that this resolution be declared null and void. On December 6, 2016, the Segunda Sección de la Sala Superior (Second Section of the Superior Court) of the Tax and Administrative Federal Court issued a judgment declaring the resolution null and void. On January 27, 2017, the SFP filed a motion to review this judgment, which was granted (file R.F.-66/2017-V) by the Octavo Tribunal Colegiado en Materia Administrativa del Primer Circuito (Eighth Administrative Joint Court of the First Circuit). The plantiff also filed a motion to review the resolution

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and an amparo, which was considered untimely and was denied on April 10, 2017 (D.A.-257/2017-V). The plaintiff filed a complaint against this resolution (No. 9/2017), which was denied on May 10, 2017. As of the date of this report, this proceeding has concluded. In addition, on June 25, 2013, the second administrative proceeding concluded, and the SFP fined Ms. Miyazaki Hara for Ps. 59.3 million and banned her from holding public sector positions for 20 years. On September 23, 2013, Ms. Miyazaki Hara filed a motion against this resolution before the Octava Sala Regional Metropolitana (Eighth Regional Metropolitan Court) of the Federal Court of Tax and Administrative Justice seeking that this additional resolution also be declared null and void, which was granted on February 20, 2017 (file No. 66/2017-V). On January 30, 2017, the SFP filed a motion to review this judgment, which was admitted (file R.F.-77/2017-II) by the Eighth Administrative Joint Court of the First Circuit. The plaintiff also filed a motion to review the resolution and an amparo, which was considered untimely and was denied on April 11, 2017 (D.A.-261/2017-II). The plaintiff filed a complaint against this resolution (No. 11/2017), which was denied on May 12, 2017. As of the date of this annual report, this proceeding has concluded.

In December 2010, the SFP issued a resolution imposing penalties against 15 public sector employees for being involved in irregularities related to the leasing procedures for four vessels. The employees were fined and barred from public sector employment for a period of ten years. The employees appealed the penalties. The penalties imposed by the resolution issued by the SFP were declared null and void in ten cases and valid in four cases. In the final pending case, Mr. Zermeño Díaz filed an amparo, which was denied on July 10, 2014, by the el Cuarto Tribunal Colegiado en Materia Administrativa del Primer Circuito (Fourth Administrative Joint Court of the First Circuit). As of the date of this annual report, this proceeding has concluded.

On October 11, 2011, the SFP announced that it had fined three former officers of PMI an aggregate amount of Ps. 267.8 million, for allegedly improper contracting practices in the purchase and/or sale of petroleum products, which allegedly benefited certain of PMI’s commercial counterparties. The implicated former officers of PMI were also barred from public sector employment for a period of ten years. These former officers appealed the penalties. Two motions were granted and the resolutions declared null and void. On February 8, 2017, a judgment was issued by the Sala Superior (Higher Court) of the Tribunal Federal de Justicia Administrativa (Federal Court of Administrative Justice) declaring the third resolution null and void. On April 3, 2017, the SFP filed a motion to review this resolution and the former officer filed an amparo (file No. D.A. 198/2017) before the Quinto Tribunal Colegiado en Materia Administrativa del Primer Circuito (Fifth Joint Administrative Court of the First Circuit). On February 15, 2018, a judgment was issued declaring the judgment issued in February 2017 valid. As of the date of this annual report, this matter has concluded.

In July 2011, a criminal complaint was filed against Mario Blenda Ahumada, former Deputy Director of Trade and Refined Products of PMI, after a Ps. 11.0 million increase in his personal assets was detected. The Federal Attorney General’s Office concluded its investigation without filing a criminal complaint. The SFP filed a motion against this resolution, which was granted. As of the date of this annual report, the investigation is ongoing to determine whether criminal charges will be brought.

On April 24, 2014, the SFP issued a resolution imposing penalties against several public sector employees in connection with operations executed with Oceanografía, S.A. de C.V. Four employees of Pemex-Exploration and Production were barred from public sector employment for six months to one year. The employees filed motions (files No. 14/8891-19-01-02-08-OT; 10781/14-17-10-5; 16172/14-17-04-7; and 15972/14-17-11-4) before the Regional Court of Chiapas-Tabasco and the Décima Sala Regional Metropolitana (Tenth Regional Metropolitan Court), the Cuarta Sala Regional Metropolitana (Fourth Regional Metropolitan Court) and the Décima Primera Sala Regional Metropolitana (Eleventh Regional Metropolitan Court) of the Federal Court of Tax and Administrative Justice, respectively, requesting that the penalties be declared null and void. The following sets forth the status of these proceedings:

• On April 4, 2015, a judgment was issued (file No. 14/8891-19-01-02-08-OT) declaring the resolution null and void and requesting that a new judgment be issued. On September 29, 2016, a new resolution

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was issued and the employee filed a new administrative claim (file No. 518/16-26-01-2) before the Sala Regional de Tabasco del Tribunal de Justicia Administrativa (Regional Court of Tabasco of the Administrative Justice Court). On June 29, 2017, a judgment was issued declaring the resolution null and void. The SFP filed a motion to review this resolution before the Joint Administrative and Labor Court of the Tenth Circuit (file No. R.F. 32/2017). As of the date of this report, a final resolution is still pending.

• On May 9, 2015, a judgment was issued (file No. 10781/14-17-10-5) declaring the resolution valid. On December 14, 2016, the employee filed an amparo requesting that a new judgment be issued, which was granted. On June 27, 2017, a new resolution was issued declaring the resolution against the employee valid. The employee subsequently filed an amparo before the Eighth Administrative Joint Court of the First Circuit (file D.A. 638/2017). As of the date of this report, a new judgment is still pending.

• On February 15, 2015, a judgment was issued (file No. 16172/14-17-04-7) declaring the resolution null and void. On August 11, 2016, the Tribunal Colegiado de Circuito (Circuit Court) dismissed the judgment and remanded for issuance of a new resolution. On March 1, 2017, a new judgment was issued declaring the resolution null and void, which was confirmed by the Joint Circuit Court on October 23, 2017.

• On March 19, 2015, a judgment was issued (file No. 15972/14-17-11-4) declaring the resolution null and void, which was sustained by the Circuit Court on October 16, 2015.

Key Energy Services

On August 11, 2016, the SEC announced that Key Energy Services, Inc. agreed to pay U.S. $5 million to settle SEC charges that it violated the internal controls and books-and-records provisions of the Foreign Corrupt Practices Act. These violations arose from payments allegedly made by its subsidiary, Key Mexico, to one of our employees to induce him to provide advice, assistance and inside information that was used by Key Energy and Key Mexico in negotiating contracts with us. The Liabilities Unit at Petróleos Mexicanos started an investigation and, as of the date of this annual report, the investigation is ongoing.

Odebrecht

On December 21, 2016, the U.S. Department of Justice publicly disclosed that Odebrecht, a global construction conglomerate based in Brazil, pled guilty to charges of bribery and corruption in connection with, among other things, bribes paid for more than 100 projects in twelve countries. The report further disclosed that, between 2010 and 2014, Odebrecht had bribed officials of the Mexican government for an amount equal to U.S. $10.5 million, including the payment to a high-level official of a Mexican state-owned and state-controlled company of a bribe of U.S. $6 million.

On December 22, 2016, the Liabilities Unit commenced an investigation into instances of bribery or corruption related to these allegations. On January 25, 2017, we filed a criminal complaint with the Federal Attorney General’s Office against any party for acts that may have been committed against PEMEX.

As a result investigations being conducted by the Liabilities Unit, SFP and Federal Attorney General’s Office, agreements executed by Odebrecht and its affiliates with various public entities of the Mexican Government have been and are continuing to be reviewed. As of the date of this annual report, the SFP has initiated eight administrative sanctioning procedures: four against Odebrecht and its affiliates, two against their legal representatives and two against employees of PEMEX. The results of these investigations have resulted in the following actions:

• On June 14, 2017, the Ministry of the Public Function, through the Liabilities Unit, initiated four administrative sanctioning procedures against two affiliates of Odebrecht and its representatives for probable wrongful payments related to a public work contract in our Miguel Hidalgo refinery.

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• On June 16, 2017, we notified Odebrecht Ingeniería y Construcción Internacional de México, S.A. de C.V. (“ODM”) of the termination of the engineering, procurement and construction contract between ODM and Pemex Industrial Transformation dated November 12, 2015. This contract was valued at Ps. 1.8 billion and covered works related to the construction of access ways and external works for the residual exploitation project for the Miguel Hidalgo refinery. We terminated this contract due to ODM’s failure to comply with its obligations.

• On September 11, 2017 and October 8, 2017, the SFP, through the Liabilities Unit, announced that it had identified additional irregularities in connection with payments of Ps. 119 million and Ps. 2.5 million, respectively, related to the execution of public work contracts in our Miguel Hidalgo refinery involving an affiliate of Odebrecht and a public officer of Pemex Industrial Transformation.

• On December 11, 2017, the SFP announced it has banned Constructora Norberto Odebrecht, S.A. from bidding for and entering into Mexican Government contracts and contracts with PEMEX, for four years and two years, respectively, as a result of having wrongfully received Ps. 119 million pesos in connection with one of the public work contracts executed for our Miguel Hidalgo refinery.

• On December 15, 2017, the SFP announced that it had fined an officer of Pemex Industrial Transformation in the amounts of Ps. 119 million and Ps. 2.5 million and also barred such officer from public sector employment for a period of ten years.

• On April 17, 2018, the Liabilities Unit announced that it has banned each of ODM and Constructora Norberto Odebrecht, S.A for two years and six months from bidding for and entering into Mexican government contracts, including contracts with PEMEX, and fined each of them in an aggregate amount of Ps. 543.5 million for wrongful acts committed in connection with, and failure to comply with the requirements of, the contract executed with Pemex Industrial Transformation for the Miguel Hidalgo refinery. The SFP also announced it has banned each of the Director General, Mr. Luis Alberto de Meneses Weyll, and the Director of Management and Finance, Mr. Gleiber José de Faria, of ODM, for two years and three months and fined each of them in an aggregate amount of Ps. 1.26 million for wrongful acts committed in connection with, and failure to comply with the requirements of, the contract executed with Pemex Industrial Transformation for the Miguel Hidalgo refinery.

The administrative sanctions imposed by the SFP are independent of any criminal charges that may be brought as a result of the criminal investigation that is being carried out by the Attorney General’s Office, which, as of the date of this annual report, is still ongoing.

We are collaborating with the SFP, the Liabilities Unit, and the Federal Attorney General’s Office in order to hold those responsible for these acts accountable and ensure that we recover any damages to which we are entitled.

Actions Against the Illicit Market in Fuels

In order to counteract the illicit fuel market, we have implemented a security strategy throughout our facilities that seeks to:

• integrate a strategic safeguard system, allowing us to respond in a timely manner to risks of illegal activity;

• strengthen coordination and collaboration between Petróleos Mexicanos and our subsidiary entities, as well as with authorities in the three orders of government, including the Federal Attorney General’s Office, Federal Consumer’s Office, Tax Administration System, federal, state and municipal police, the Secretaría de la Defensa Nacional (Ministry of National Defense) and the Mexican navy;

• optimize our human capital and modernize our technology;

• modernize our information systems to improve our strategic decision making and our response time; and

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• revise our security strategy to incorporate innovations from the fields of industrial safety, civil protection, and environmental preservation.

Our initiatives aim to develop a sustainable operating model to safeguard the areas in which we operate, which comprise approximately 2.0 million square kilometers of onshore fields and 3.2 million square kilometers of Mexican territorial waters.

These initiatives are intended to strengthen our ability to combat the illicit market in fuels, and include our increased investments in surveillance technology for our facilities and pipelines, as well as the reinforcement of equipment and resources available to protect our personnel, facilities, the general population and the environment. In particular, during 2017, we continued the following strategic measures in order to decrease incidents of criminal activity at our facilities:

• Worked with the judicial and ministerial authorities to identify 6,660 vehicles involved in the illicit market in fuels, as compared to 2,695 vehicles in 2016, which represents a 147.1% increase. The number of individuals brought before judicial authorities in connection with the illicit market in fuels increased to 976, as compared to 583 individuals brought before judicial authorities in 2016, which represents a 67.4% increase, mainly due to implementation of the Sistema de Justicia Penal Acusatorio (Adversarial System in Criminal Justice), which requires that law enforcement, not our personnel, act as first responders to any suspected participation in hydrocarbon related crime, irrespective of whether we, or any other group initially discovered the illegal activity.

• Inspected the rights of way and facilities through a total of 19,587,523 kilometers patrolled in 2017, at an average of 52,058 kilometers per day by vehicle and 1,606 kilometers per day by foot, as compared to 305 kilometers per day by foot and 28,693 kilometers per day by vehicles during 2016, which represents an increase of 87.03% in total kilometers patrolled. These surveillance activities were carried out in coordination with the Ministry of National Defense, the Mexican Navy and other governmental authorities.

• Strengthened our collaborations with governmental entities, the Federal Attorney General’s Office, the federal police and the Ministry of the Interior, among others, to share information and provide support to investigative teams focused on theft and illegal trade in fuels. We have also provided training for authorities responsible for the prevention, detection and prosecution of criminal activities in the illicit market in fuels, particularly in the inspection of automobile tanks and the documentation needed to be able to transport fuel, in an effort to support intragovernmental coordination.

• Created territorial divisions to best use monitoring technologies along with our ground patrol, which has allowed us to detect a higher number of illegal drillings and to prevent the illegal extraction of fuels.

These measures led to the recovery of 22.6 million liters of hydrocarbon product in 2017, which represents an increase of approximately 72.5% as compared to the 13.1 million liters recovered in 2016.

These efforts also led to the identification and sealing of 10,316 illegal pipeline taps in 2017, as compared to the identification and sealing of 6,873 illegal pipeline taps during 2016, which represents a 50.1% increase. This increase resulted from both increased surveillance and an increase in the number of criminal attempts to divert our products. Our renewed focus on the detection of illegal pipeline taps in 2017 enabled us to collect more information and develop more effective strategies to combat fuel theft, which in turn improved our ability to deploy ground patrol for the immediate identification and sealing of pipeline taps and prevent additional extraction of our hydrocarbon products.

On June 1, 2017, we announced the cancellation of the franchise contracts of seven gas stations located in the state of Puebla, which allegedly committed irregularities in their fuel trade procedures and had tax inconsistencies. The announcement was the result of an operation involving PEMEX, the Secretaría de Hacienda

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y Crédito Público (Ministry of Finance and Public Credit) through the Tax Administration Service and its Financial Intelligence Unit, as well as the Procuraduría General de la República (Attorney General’s Office), the Secretaría de la Defensa Nacional (Ministry of National Defense) and the Comisión Nacional de Seguridad (National Security Commission), through the federal and state police. Through measures like these, we seek to provide certainty to our customers, as well as to combat the illicit market in fuels, tax evasion, money laundering and commercial fraud.

On February 14, 2018, the Liabilities Unit at Petróleos Mexicanos imposed penalties on eight employees from the storage and distribution terminal of Pemex Logistics in the state of Chihuahua for operating technological devices to alter the measurement parameters to fill fuel tankers and for deviating from expected routes. Three of these employees were dismissed and barred from holding public sector positions for one year and five employees were suspended. On March 14, 2018, the Liabilities Unit at Petróleos Mexicanos dismissed another three employees from Sector Pipelines Bajío of Pemex Logistics and barred them from holding public sector positions for ten years for the tapping of diesel in the Tula-Salamanca pipeline in Celaya, Guanajuato.

On March 27, 2018, the Liabilities Unit at Petróleos Mexicanos suspended an employee from Sector Pipelines Minatitlán of Pemex Logistics. This employee allegedly belongs to an organized network that repeatedly manipulated and altered the valves of the Minatitlán-México pipeline in Acayucan, Veracruz.

Civil Actions

In the ordinary course of our business, we are a party to a number of lawsuits of various types. We evaluate the merit of each claim and assess the likely outcome, accruing a contingent liability when an unfavorable decision is probable and the amount is reasonably estimable. At December 31, 2016 and 2017, we had accrued a reserve of Ps. 15.1 billion and Ps. 7.8 billion, respectively, for our contingent liabilities in connection with these lawsuits. Our material legal proceedings are described in Note 25 and Note 27 to our audited financial statements included in this report, and those descriptions are incorporated by reference under this Item.

Dividends

Pursuant to the Petróleos Mexicanos Law, as of January 1, 2016, Petróleos Mexicanos and its subsidiary entities are subject to a new dividend policy that will require them to pay a state dividend to the Mexican Government on an annual basis. In accordance with the Federal Revenue Law of 2017 and the Federal Revenue Law of 2018, Petróleos Mexicanos was not required to pay a state dividend in 2017 and will not be required to pay a state dividend in 2018. For more information, see “Item 4—Taxes, Duties and Other Payments to the Mexican Government—Fiscal Regime for PEMEX—Other Payments to the Mexican Government.”

Item 9. The Offer and Listing

Trading in the debt securities issued by Petróleos Mexicanos takes place primarily in the over-the-counter market. All the debt securities issued by Petróleos Mexicanos that are registered pursuant to the U.S. Securities Act of 1933 (which we refer to as the Securities Act) are also listed on the Luxembourg Stock Exchange and traded on the Euro MTF market of the Luxembourg Stock Exchange.

Item 10. Additional Information

Memorandum and Articles of Association

The Mexican Congress established Petróleos Mexicanos by a decree dated June 7, 1938, effective July 20, 1938. None of Petróleos Mexicanos or the subsidiary entities has bylaws or articles of association. Petróleos Mexicanos and the subsidiary entities, are public entities of the Mexican Government and each is a legal entity empowered to own property and carry on business in its own name.

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The activities of Petróleos Mexicanos and the subsidiary entities are regulated by the Mexican Constitution, the Petróleos Mexicanos Law, Regulations to the Petróleos Mexicanos Law, the Hydrocarbons Law and other federal laws and regulations. See “Item 4—Information on the Company—History and Development.” Under the Petróleos Mexicanos Law, the Board of Directors of Petróleos Mexicanos has the following committees: the Audit Committee, the Human Resources and Compensation Committee, the Strategy and Investment Committee and the Acquisitions, Leasing, Public Works and Services Committee. See “Item 6—Directors, Senior Management and Employees.”

Under the Petróleos Mexicanos Law and the Regulations to the Petróleos Mexicanos Law, our directors are obligated to abstain from voting on a proposal, arrangement or contract in which they have a personal, family or business interest. Our directors do not have the power to vote compensation to themselves or any other member of the board. Except in the case of the independent board members, our directors do not receive compensation for their services as members of the boards of directors of Petróleos Mexicanos and the subsidiary entities. Under the Petróleos Mexicanos Law, our directors must perform their duties without obtaining or attempting to obtain any benefits greater than those granted by law. Therefore, our directors do not have borrowing powers exercisable by themselves. There is no requirement for early retirement for our directors.

Material Contracts

As of December 31, 2016 and 2017, we have entered into contracts with various contractors for approximate amounts of Ps. 817,994 million and Ps. 698,905 million, respectively. These contracts are for the development of investment projects. See Note 24(e) to our consolidated financial statements included herein.

On January 27, 2009, Petróleos Mexicanos entered into an indenture with Deutsche Bank Trust Company Americas, as Trustee. This agreement provides for the issuance by Petróleos Mexicanos from time to time of unsecured debt securities. On the same date, Petróleos Mexicanos entered into a distribution agreement with Calyon Securities (USA) Inc. (now known as Credit Agricole Securities (USA) Inc.), Citigroup Global Markets Inc., Citigroup Global Markets Limited, HSBC Securities (USA) Inc. and Santander Investment Securities Inc. pursuant to which Petróleos Mexicanos established a U.S. $7.0 billion medium-term note, Series C, program. Pursuant to the 1996 guaranty agreement referred to above, Petróleos Mexicanos’ obligations under all notes issued under this program are jointly and severally guaranteed by Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals. In December 2010, Petróleos Mexicanos appointed Credit Suisse Securities (USA) LLC as an agent under the 2009 distribution agreement referred to above. In each of December 2010 and January 2010, Petróleos Mexicanos increased the size of this program to U.S. $12.0 billion and U.S. $22.0 billion, respectively. Petróleos Mexicanos issued U.S. $3.5 billion of notes and bonds under this program in 2011. In 2012, Petróleos Mexicanos issued U.S. $5.3 billion of notes and bonds under this program. In 2013, Petróleos Mexicanos increased the size of this program to U.S. $32.0 billion and issued U.S. $6.9 billion of notes and bonds under it. In 2014, Petróleos Mexicanos increased the size of this program to U.S. $42.0 billion and issued U.S. $7.9 billion of notes and bonds under it. In 2017, Petróleos Mexicanos increased the size of this program to U.S. $92.0 billion and issued €4.3 billion, U.S. $5.0 billion and £450.0 million of notes and bonds under it. During the first three months of 2018, Petróleos Mexicanos increased the size of this program to U.S. $102.0 billion and issued U.S. $4.0 billion of notes and bonds under it. See “Item 5—Operating and Financial Review and Prospects—Liquidity and Capital Resources—Financing Activities.”

Exchange Controls

Mexico has had a free market for foreign exchange since 1991, and the Mexican Government has allowed the peso to float freely against the U.S. dollar since December 1994. We have no control over or influence on this exchange rate policy. The Mexican Government has announced that it does not intend to change its floating exchange rate policy, but there is no guarantee that the Mexican Government will not change this policy. See “Item 3—Key Information—Exchange Rates.”

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Taxation

The 1997 Securities, the 1999 Securities, the 2003 Securities, the 2004 Securities, the 2006 Securities, the 2008 Securities, the 2009 Securities, the 2010 Securities, the 2011 Securities, the 2012 Securities, the 2013 Securities, the 2014 Securities, 2016 and the 2017 Securities.

As of the date of this annual report, we have registered the following securities (the “Registered Securities”) with the Securities and Exchange Commission.

Pursuant to a registration statement on Form F-4 (File No. 333-7796), which was declared effective by the SEC on October 17, 1997, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $400,000,000 of 9.50% Global Guaranteed Bonds due 2027, which we refer to as the 1997 Securities. In December 2004 and February 2006, an aggregate amount of U.S. $376,250,000 of the 1997 Securities were exchanged for bonds issued by the Pemex Project Funding Master Trust (which we refer to as the Master Trust).

Pursuant to a registration statement on Form F-4 (File No. 333-10706), which was declared effective by the SEC on October 1, 1999, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $500,000,000 of 9.50% Puttable or Mandatorily Exchangeable Securities (POMES^SM) due 2027, which we refer to as the 1999 Securities. In December 2004 and February 2006, an aggregate amount of U.S. $421,522,000 of the 1999 Securities were exchanged for POMES^SM issued by the Master Trust. All outstanding 1999 Securities of Petróleos Mexicanos were, on March 16, 2006, mandatorily exchanged for 9.50% Global Guaranteed Bonds due 2027 issued by Petróleos Mexicanos, thereby increasing the outstanding amount of the 1997 Securities.

Pursuant to a registration statement on Form F-4 (File No. 333-103197), which was declared effective by the SEC on February 24, 2003, the Master Trust, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $500,000,000 of 8.625% Bonds due 2022. Pursuant to a registration statement on Form F-4 (File No. 333-107905), which was declared effective by the SEC on August 21, 2003, the Master Trust, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $510,154,000 of 8.625% Bonds due 2022. We refer to the securities registered in 2003 under these registration statements as the 2003 Securities.

Pursuant to a registration statement on Form F-4 (File No. 333-118373), which was declared effective by the SEC on August 31, 2004, the Master Trust, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $47,085,000 of 8.625% Bonds due 2022. We refer to the securities registered in 2004 as the 2004 Securities.

Pursuant to a registration statement on Form F-4 (File No. 333-126941), which was declared effective by the SEC on January 13, 2006, the Master Trust, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $228,735,000 of 8.625% Bonds due 2023, U.S. $354,477,000 of 9.50% Bonds due 2027, U.S. $403,746,000 of POMES^SM due 2027 and U.S. $500,000,000 of 6.625% Guaranteed Bonds due 2035. Pursuant to a registration statement on Form F-4 (File No. 333-126948), which was declared effective by the SEC on January 13, 2006, the Master Trust, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $21,265,000 of 8.625% Bonds due 2023, U.S. $45,523,000 of 9.50% Bonds due 2027 and U.S. $96,254,000 of POMES^SM due 2027. All outstanding POMES registered under these registration statements were, on March 15, 2006, mandatorily exchanged for 9.50% Bonds due 2027. Pursuant to a registration statement on Form F-4 (File No. 333-136674), which was declared effective by the SEC on November 3, 2006, the Master Trust, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $751,995,000 of 6.625% Guaranteed Bonds due 2035. We refer to the securities registered in 2006 under these registration statements as the 2006 Securities.

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Pursuant to a registration statement on Form F-4 (File No. 333-152486), which was declared effective by the SEC on December 18, 2008, the Master Trust, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $501,000,000 of 6.625% Guaranteed Bonds due 2035 and up to U.S. $500,000,000 of 6.625% Guaranteed Bonds due 2038. We refer to the securities registered in 2008 as the 2008 Securities.

Pursuant to a registration statement on Form F-4 (File No. 333-160799), which was declared effective by the SEC on August 25, 2009, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $2,000,000,000 of 8.00% Notes due 2019. We refer to the securities registered in 2009 as the 2009 Securities.

Effective as of September 30, 2009, Petróleos Mexicanos assumed, as primary obligor, all of the Master Trust’s obligations as issuer of the 2001 Securities, the 2003 Securities, the 2004 Securities, the 2006 Securities and the 2008 Securities. As a result, effective as of September 30, 2009, Petróleos Mexicanos is the issuer of all Registered Securities (as defined below).

Pursuant to a registration statement on Form F-4 (File No. 333-168326), which was declared effective by the SEC on August 31, 2010, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $63,314,000 of 8.00% Notes due 2019, up to U.S. $1,000,000,000 of 6.000% Notes due 2020, up to U.S. $2,000,000,000 of 5.50% Notes due 2021 and up to U.S. $1,000,000,000 of 6.625% Bonds due 2035. We refer to the securities registered in 2010 as the 2010 Securities.

Pursuant to a registration statement on Form F-4 (File No. 333-175821), which was declared effective by the SEC on August 31, 2011, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $1,000,000,000 of 5.50% Notes due 2021 and up to U.S. $1,250,000,000 of 6.500% Bonds due 2041. We refer to the securities registered in 2011 as the 2011 Securities.

Pursuant to a registration statement on Form F-4 (File No. 333-182553), which was declared effective by the SEC on July 23, 2012, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $2,100,000,000 of 4.875% Notes due 2022 and up to U.S. $1,750,000,000 of 5.500% Bonds due 2044. We refer to the securities registered in 2012 as the 2012 Securities.

Pursuant to a registration statement on Form F-4/A (File No. 333-189852), which was declared effective by the SEC on July 25, 2013, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $1,000,000,000 of 3.500% Notes due 2018, up to U.S. $500,000,000 of Floating Rate Notes due 2018, up to U.S. $2,100,000,000 of 3.500% Notes due 2023, up to U.S. $1,000,000,000 of 4.875% Notes due 2024, up to U.S. $500,000,000 of 6.500% Bonds due 2041 and up to U.S. $1,000,000,000 of 5.50% Bonds due 2044. We refer to the securities registered in 2013 as the 2013 Securities.

Pursuant to a registration statement on Form F-4 (File No. 333-198588), which was declared effective by the SEC on September 22, 2014, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex-Refining and Pemex-Gas and Basic Petrochemicals registered pursuant to the Securities Act up to U.S. $500,000,000 of 3.125% Notes due 2019, up to U.S. $500,000,000 of 4.875% Notes due 2024 and up to U.S. $3,000,000,000 of 6.375% Bonds due 2045. We refer to the securities registered in 2014 as the 2014 Securities.

Pursuant to a registration statement on Form F-4 (File No. 333-205763), which was declared effective by the SEC on February 22, 2016, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services registered

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pursuant to the Securities Act up to U.S. $1,500,000,000 of 3.500% Notes due 2020, up to U.S. $1,000,000,000 of 4.250% Notes due 2025, $1,500,000,000 of 4.500% Notes due 2026, up to U.S. $1,500,000,000 of 5.50% Bonds due 2044 and up to U.S. $3,000,000,000 of 5.625% Bonds due 2046. Pursuant to a registration statement on Form F-4 (File No. 333-213351), which was declared effective by the SEC on November 11, 2016, Petróleos Mexicanos, Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services registered pursuant to the Securities Act up to U.S. $750,000,000 of 5.500% Notes due 2019, up to U.S. $1,250,000,000 of 6.375% Notes due 2021, up to U.S. $2,069,302,000 of 4.625% Notes due 2023, up to U.S $3,000,000,000 of 6.875% Notes due 2026, and up to U.S.$3,500,000,000 of 6.750% Notes due 2047. We refer to the securities registered in 2016 as the 2016 Securities.

Pursuant to a registration statement on Form F-4 (File No. 333-220721), which was declared effective by the SEC on February 22, 2018, Petróleos Mexicanos, Pemex-Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services registered pursuant to the Securities Act up to U.S. $1,500,000,000 5.375% Notes due 2022, up to U.S. $1,000,000,000 Floating Rate Notes due 2022, up to U.S. $5,500,000,000 6.500% Notes due 2027 and up to U.S. $2,500,000,000 6.750% Bonds due 2047. We refer to the securities registered in 2018 as the 2018 Securities and together with the 1997 Securities, the 2003 Securities, the 2004 Securities, the 2006 Securities, the 2008 Securities, the 2009 Securities, the 2010 Securities, the 2011 Securities, the 2012 Securities, the 2013 Securities, the 2014 Securities and the 2016 Securities as the Registered Securities.

Taxation Generally

The following summary contains a description of the principal Mexican and U.S. federal income tax consequences of the ownership and disposition of the Registered Securities, but it does not purport to be a comprehensive description of all of the tax considerations that may be relevant to a decision to invest in, or dispose of, the Registered Securities.

This summary is based on the federal tax laws of Mexico and the United States in force on the date of this Form 20-F, including the provisions of the income tax treaty between the United States and Mexico together with related protocols (which are subject to change), and does not describe any tax consequences arising under the laws of any state or municipality in Mexico, the United States or any other jurisdiction, or the laws of any taxing jurisdiction other than the federal laws of Mexico and the United States.

Mexico has also entered into, or is negotiating, tax treaties with various countries that may have effects on holders of Registered Securities. This report does not discuss the consequences (if any) of such treaties.

Each holder or beneficial owner of Registered Securities should consult its tax advisor as to the Mexican, United States or other tax consequences of the ownership and disposition of those securities, including the effect of any foreign, state or municipal tax laws, and the consequences of the application of any tax treaty to which Mexico is a party.

Mexican Taxation

This summary of certain Mexican federal tax considerations refers only to holders of Registered Securities that are not residents of Mexico for Mexican tax purposes and that will not hold the Registered Securities or a beneficial interest therein through a permanent establishment for tax purposes (we refer to any such non-resident holder as a Foreign Holder). For purposes of Mexican taxation, an individual is a resident of Mexico if he/she has established his/her domicile in Mexico. When an individual also has a place of residence in another country, that individual will be considered a resident of Mexico for tax purposes, if such individual has his/her center of vital interest in Mexico. An individual would be deemed to have his/her center of vital interest in Mexico if, among other things: (a) more than 50% of his/her total income for the year were derived from Mexican sources, or (b) his/her principal center of professional activities were located in Mexico.

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A legal entity is a resident of Mexico if:

• it maintains the principal administration of its business in Mexico; or

• it has established its effective management in Mexico.

A Mexican national is presumed to be a resident of Mexico unless such person can demonstrate the contrary. If a legal entity or individual has a permanent establishment in Mexico, such permanent establishment shall be required to pay taxes in Mexico on income attributable to such permanent establishment in accordance with Mexican federal tax law.

Taxation of Interest. Under the Mexican Income Tax Law and rules issued by the Ministry of Finance and Public Credit applicable to PEMEX, payments of interest (which are deemed to include any amounts paid in excess of the original issue price of the relevant securities), made by a Mexican issuer (including Petróleos Mexicanos) in respect of notes or bonds and other debt securities to a Foreign Holder will generally be subject to a Mexican withholding tax assessed at a rate of 4.9%, if the following requirements are met:

• notice relating to the offering of such notes or bonds is given to the CNBV as required under the Securities Market Law and evidence of such notice is timely filed with the Ministry of Finance and Public Credit;

• such notes or bonds are placed outside of Mexico through banks or brokerage houses in a country that is party to a treaty to avoid double taxation with Mexico; and

• the issuer duly complies with the information requirements established in the general rules issued by the Ministry of Finance and Public Credit for such purposes.

If the effective beneficiaries, directly or indirectly, individually or jointly with related parties, receive more than 5% of the interest paid on such notes or bonds and are holders, directly or indirectly, individually or jointly, with related parties of more than 10% of the voting stock of the issuer or entities 20% or more of whose stock is owned directly or indirectly, individually or jointly, by parties related to the issuer, the withholding tax rate applicable to payment of interest on such notes or bonds may be significantly higher.

Payments of interest made by Petróleos Mexicanos or the subsidiary entities, except for Pemex Fertilizers and Pemex Ethylene, in respect of the Registered Securities to non-Mexican pension or retirement funds will be exempt from Mexican withholding taxes, provided that:

• such fund is duly organized pursuant to the laws of its country of origin and is the effective beneficiary of the interest payment;

• the income from such interest payment is exempt from income tax in its country of residence; and

• such fund delivers certain information as per rules issued by the Ministry of Finance and Public Credit.

Additional Amounts. Petróleos Mexicanos and the subsidiary entities, except for Pemex Fertilizers and Pemex Ethylene, have agreed, subject to specified exceptions and limitations, to:

• pay Additional Amounts (as defined in the indenture dated as of September 18, 1997, as supplemented, between Petróleos Mexicanos and Deutsche Bank) to the holders of the 1997 Securities in respect of the Mexican withholding taxes mentioned above;

• pay Additional Amounts (as defined in the indenture dated as of August 7, 1998, as supplemented, between Petróleos Mexicanos and Deutsche Bank) to the holders of the 1998 Securities in respect of the Mexican withholding taxes mentioned above;

• pay Additional Amounts (as defined in the indenture dated as of July 31, 2000, as supplemented, between Petróleos Mexicanos and Deutsche Bank) to the holders of the 2003 Securities and the 2004 Securities in respect of the Mexican withholding taxes described above;

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• pay Additional Amounts (as defined in the indenture dated as of December 30, 2004, as supplemented, between Petróleos Mexicanos and Deutsche Bank) to the holders of the 2006 Securities and the 2008 Securities in respect of the Mexican withholding taxes described above; and

• pay Additional Amounts (as defined in the indenture dated as of January 27, 2009, as supplemented, between Petróleos Mexicanos and Deutsche Bank) to the holders of the 2009 Securities, the 2010 Securities, the 2011 Securities, the 2012 Securities, the 2013 Securities, the 2014 Securities and the 2016 Securities in respect of the Mexican withholding taxes described above.

If Petróleos Mexicanos pays Additional Amounts in respect of such Mexican withholding taxes, any refunds received with respect to such Additional Amounts will be for the account of Petróleos Mexicanos.

Holders or beneficial owners of the Registered Securities may be required to provide certain information or documentation necessary to enable Petróleos Mexicanos and the subsidiary entities to apply the appropriate Mexican withholding tax rate applicable to holders or beneficial owners of the Registered Securities. In the event that the specified information or documentation concerning such holder or beneficial owner, if requested, is not provided on a timely basis, the obligation of Petróleos Mexicanos and the subsidiary entities to pay Additional Amounts may be limited.

Taxation of Dispositions. Capital gains resulting from the sale or other disposition of the Registered Securities by a Foreign Holder will not be subject to Mexican income or withholding taxes.

Other Mexican Tax Considerations. Under the Income Tax Law, any discount received by a non-resident upon purchase of the notes or bonds from a Mexican resident or a non-resident with a permanent establishment in Mexico is deemed interest income, and therefore, subject to taxes in Mexico. Such interest income results from the difference between the face value (plus accrued interest not subject to withholding) and the purchase price of such notes or bonds.

Transfer and Other Taxes. There are no Mexican stamp, registration or similar taxes payable by a Foreign Holder in connection with the purchase, ownership or disposition of the Registered Securities. A Foreign Holder of the Registered Securities will not be liable for Mexican estate, succession, gift, inheritance or similar tax with respect to such securities.

United States Taxation

This summary of certain U.S. federal income tax considerations deals principally with persons that hold the Registered Securities as capital assets and whose functional currency is the U.S. dollar. As used in this section “Taxation,” the term “United States Holder” means a beneficial owner of a Registered Security that is an individual who is a citizen or resident of the United States, a U.S. domestic corporation or any other person that is subject to U.S. federal income taxation on a net income basis in respect of its investment in the Registered Securities.

This summary does not purport to be a comprehensive description of all the tax considerations that may be relevant to any particular investor, including tax considerations that arise from rules of general application or that are assumed to be known to investors. This summary generally does not address the tax treatment of holders that may be subject to special tax rules, such as banks, insurance companies, tax-exempt organizations, dealers in securities or currencies, certain short-term holders of Registered Securities, traders in securities electing to mark-to-market, or persons that hedge their exposure in the Registered Securities or hold the Registered Securities as a position in a “straddle” for tax purposes or as part of a “synthetic security” or a “hedging” or “conversion” transaction or other integrated investment comprised of such Registered Securities and one or more other investments, nonresident aliens present in the United States for more than 182 days in a taxable year, U.S. expatriates, entities taxed as partnerships or the partners therein, persons that have a “functional currency” other

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than the U.S. dollar, nor does it address the tax treatment of holders that did not acquire the Registered Securities at their issue price as part of the initial distribution. Investors who purchased the Registered Securities at a price other than the issue price should consult their tax advisor as to the possible applicability to them of the amortizable bond premium or market discount rules.

In addition, this summary does not discuss the application of the Medicare contribution tax on net investment income or the alternative minimum tax. United States Holders should consult their own tax advisers concerning the U.S. federal, state, local, and other tax consequences of purchasing, owning, and disposing of a Registered Security in their particular circumstances.

United States Holders that use an accrual method of accounting for tax purposes (“accrual method holders”) generally are required to include certain amounts in income no later than the time such amounts are reflected on certain financial statements (the “book/tax conformity rule”). The application of the book/tax conformity rule thus may require the accrual of income earlier than would be the case under the general tax rules described below, although it is not clear to what types of income the book/tax conformity rule applies. This rule generally is effective for tax years beginning after December 31, 2017 or, for debt securities issued with original issue discount, for tax years beginning after December 31, 2018. Accrual method holders should consult with their tax advisors regarding the potential applicability of the book/tax conformity rule to their particular situation.

Taxation of Interest and Additional Amounts. A United States Holder will treat the gross amount of interest and Additional Amounts (i.e., without reduction for Mexican withholding taxes) as ordinary interest income in respect of the Registered Securities. Mexican withholding taxes paid at the appropriate rate applicable to the United States Holder will be treated as foreign income taxes eligible, subject to generally applicable limitations and conditions, for credit against such United States Holder’s U.S. federal income tax liability, at the election of such United States Holder, or for deduction in computing such United States Holder’s taxable income, provided that the United States Holder does not elect to claim a foreign tax credit for any foreign income taxes paid or accrued for the relevant taxable year. Interest and Additional Amounts will constitute income from sources without the United States and generally will be treated separately along with other items of “passive” income for purposes of determining the credit for foreign income taxes allowed under the Internal Revenue Code of 1986, as amended.

The calculation and availability of foreign tax credits or deductions involves the application of rules that depend on a United States Holder’s particular circumstances. United States Holders should consult their own tax advisors regarding the availability of foreign tax credits and the treatment of Additional Amounts.

Taxation of Dispositions. Upon the sale, exchange or retirement of a Registered Security, a United States Holder will generally recognize a gain or loss equal to the difference between the amount realized (less any amounts attributable to accrued and unpaid interest not previously includible in gross income, which will be taxable as ordinary income) and the holder’s tax basis in such security, which is generally equal to the cost of the Registered Security to the United States Holder. Gain or loss recognized by a United States Holder on the sale, redemption or other disposition of the Registered Securities generally will be long-term capital gain or loss if, at the time of disposition, the securities have been held for more than one year. Long-term capital gain realized by an individual United States Holder is generally taxed at lower rates than short-term capital gains or ordinary income.

Non-United States Holders. Subject to the discussion below under “Backup Withholding and Information Reporting,” holders of the Registered Securities that are not United States Holders (which we refer to as Non-United States Holders) generally will not be subject to U.S. federal income or withholding tax on interest income in respect of the Registered Securities or on any gain realized on the disposition of the Registered Securities.

Backup Withholding and Information Reporting. Information returns may be filed with the Internal Revenue Service with respect to payments made to certain United States Holders of the Registered Securities. In addition,

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certain United States Holders may be subject to a backup withholding tax in respect of such payments, unless they (1) provide their accurate taxpayer identification numbers to the principal paying agent and certify that they are not subject to backup withholding or (2) otherwise establish an exemption from the backup withholding tax. Backup withholding is not an additional tax. Non-United States Holders may be required to comply with applicable certification procedures to establish that they are not United States Holders in order to avoid the application of such information reporting requirements and backup withholding tax.

Specified Foreign Financial Assets. Certain United States Holders that own “specified foreign financial assets” with an aggregate value in excess of U.S. $50,000 are generally required to file an information statement along with their tax returns, currently on Form 8938, with respect to such assets. “Specified foreign financial assets” include any financial accounts held at a non-U.S. financial institution, as well as securities issued by a non-U.S. issuer (which would include the Registered Securities) that are not held in accounts maintained by financial institutions. Higher reporting thresholds apply to certain individuals living abroad and to certain married individuals. Regulations extend this reporting requirement to certain entities that are treated as formed or availed of to hold direct or indirect interests in specified foreign financial assets based on certain objective criteria. United States Holders who fail to report the required information could be subject to substantial penalties. In addition, the statute of limitations for assessment of tax would be suspended, in whole or part. Prospective investors should consult their own tax advisors concerning the application of these rules to their investment in the Registered Securities, including the application of the rules to their particular circumstances.

Documents on Display

We are subject to the information requirements of the Exchange Act. In accordance with these requirements, we file reports, including annual reports on Form 20-F, and other information with the SEC. These materials, including this report, and the exhibits thereto, may be inspected and copied at the SEC’s public reference room at 100 F Street, N.E., Washington, D.C. 20549. Please call the SEC at 1-800-SEC-0330 for further information on the public reference rooms. In addition, any filings we make electronically with the SEC will be available to the public over the Internet at the SEC’s web site at http://www.sec.gov.

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Item 11. Quantitative and Qualitative Disclosures About Market Risk

QUALITATIVE DISCLOSURE

Policies for Risk Management and the Use of Derivative Financial Instruments

We face market risk caused by the volatility of hydrocarbon prices, exchange rates and interest rates, credit risk associated with investments and financial derivatives, as well as liquidity risk. In order to monitor and manage these risks, we have approved general provisions relating to financial risk management, which are comprised of policies and guidelines that promote an integrated framework for risk management, regulate the use of derivative financial instruments (“DFIs”), and guide the development of risk mitigation strategies.

This regulatory framework establishes that DFIs should be used only for the purpose of mitigating financial risk. The use of DFIs for any other purpose must be approved in accordance with our current internal regulation. We have a Financial Risk Working Group (FRWG) which is a specialized working group with decision-making authority on financial risk exposure, financial risk mitigation schemes, and DFIs trading of Petróleos Mexicanos, the subsidiary entities, and where applicable, subsidiary companies.

In addition, certain of the PMI subsidiaries have implemented a regulatory framework for risk management with respect to its activities, which consists of policies, guidelines and procedures to manage the market risk associated with its commodity trading activities in accordance with industry best practices, such as: the use of DFIs for financial risk mitigation purposes; the segregation of duties; valuation and monitoring mechanisms, such as the generation of a daily portfolio risk report, value at risk (VaR) computation; and VaR limits, both at a global and business unit level and the implementation of stop loss mechanisms. In addition, PMI Trading also has its own risk management subcommittee that supervises the trading of DFIs.

Approved DFIs are mainly traded on the OTC (Over the Counter) market; however, exchange traded instruments may also be used. In the case of PMI Trading, DFIs are traded on CME-ClearPort.

The different types of DFIs that we trade are described below in the subsections corresponding to each type of risk and applicable trading markets. See Note 16 to our consolidated financial statements included herein.

One of our policies is to contribute to minimizing the impact that unfavorable changes in financial risk factors have on our financial results by promoting an adequate balance between expected incoming cash flows from operations and outgoing cash flows related to our liabilities.

As part of the regulatory framework for financial risk management, we have limited and specified the counterparties with which we may trade DFIs and other financial instruments.

Given that the outstanding DFIs of Petróleos Mexicanos have been entered into for risk mitigation purposes, particularly with economic hedging purposes, there is no need to establish and monitor market risk limits.

For those portfolios with an open market risk exposure, our financial risk management regulatory framework establishes the implementation and monitoring of market risk limits such as VaR and capital at risk (an aggregation of mark-to-market (“MtM”) and profit and loss, or CaR).

We have also established credit guidelines for DFIs that Pemex Industrial Transformation offers to its domestic customers, which include the use of guarantees and credit lines. For exchange traded DFIs, we trade under the margin requirements of the corresponding exchange market, and therefore do not have internal policies for these DFIs.

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DFIs held with financial counterparties do not require collateral exchange clauses. Notwithstanding, our regulatory framework promotes credit risk mitigation strategies such as collateral exchange.

We do not have an independent third party to verify the compliance with these internal standards; however, we have internal control procedures that certify our compliance with existing policies and guidelines.

Description about Valuation Techniques

Fair Value of DFIs

We periodically evaluate our exposure to international hydrocarbon prices, interest rates and foreign currencies, and we use derivative instruments as a mitigation mechanism when potential sources of market risk are identified.

We monitor the fair value of our DFI portfolio on a periodic basis. The fair value represents the price at which one party would assume the rights and obligations of the other and is calculated for DFIs through models commonly used in the international financial markets, based on inputs obtained from major market information systems and price providers.

Our DFI portfolio is composed primarily of swaps, the prices of which are estimated by discounting flows using the appropriate factors and contains no exotic instruments that require numerical approximations for their valuation.

We value our DFIs under standard methodologies commonly applied in the financial markets, thereby we do not have an independent third party to value our DFIs. Nonetheless, we calculate the fair value of our DFIs through the tools developed by our market information providers such as Bloomberg, and through valuation models implemented in software packages used to integrate all of our business areas and accounting, such as System Applicable Products (SAP). We have no policies to designate a calculation or valuation agent.

Because our hedges are cash flow hedges, their effectiveness is preserved regardless of the variations in the underlying assets or reference variables, thus asset flows are fully offset by liabilities flows. Therefore, it is not necessary to measure or monitor the hedges’ effectiveness.

Fair value hierarchy

Our fair-value assumptions fall under Level 2 of the fair value hierarchy for market participant assumptions, as described below.

The fair values determined by Level 1 inputs utilize quoted prices in financial markets for identical assets or liabilities. Fair values determined by Level 2 inputs are based on quoted prices for similar assets or liabilities in financial markets, and inputs other than quoted prices that are observed for assets or liabilities. Level 3 inputs are unobservable inputs for the assets or liabilities, and include situations where there is little, if any, market activity for the assets or liabilities. Management uses appropriate valuation techniques based on the available inputs to measure the fair values of our applicable assets and liabilities.

When available, we measure fair value using Level 1 inputs, because they generally provide the most reliable evidence of fair value.

Liquidity Sources

Liquidity Risk

Our main internal source of liquidity comes from our operations. Additionally, through our debt planning and the purchase and sale of U.S. dollars, we currently preserve a cash balance at a level of liquidity in domestic

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currency and U.S. dollars that is considered adequate to cover our investment and operating expenses, as well as other payment obligations, such as those related to DFI’s. In order to preserve a cash balance at a suitable level, during the fourth quarter of 2017, we entered into ten FX swaps of the peso against U.S. dollar for an aggregate amount of U.S. $3.0 billion.

In addition, we have acquired committed revolving credit lines in order to mitigate liquidity risk, two of which provide access to Ps. 3,500 million and Ps. 20,000 million with expiration dates in June and November 2019, respectively, and three others that provide access to U.S. $1.5 billion, U.S. $3.3 billion and U.S. $2.0 billion with expiration dates in December 2019, February 2020 and January 2021, respectively. Finally, the investment strategies of our portfolios are structured by selecting time horizons that consider each currency’s cash flow requirements in order to preserve liquidity.

Certain PMI subsidiaries mitigate their liquidity risk through several mechanisms, the most important of which is the centralized treasury or “in-house bank,” which provides access to a syndicated credit line for up to U.S. $700 million and cash surplus capacity in the custody of the centralized structure. In addition, certain PMI subsidiaries have access to bilateral credit lines from financial institutions for up to U.S. $650 million.

These companies monitor their cash flow on a daily basis and protect their creditworthiness in the financial markets. Liquidity risk is mitigated by monitoring the maximum/minimum permissible financial ratios as set forth in the policies approved by each company’s board of directors.

Changes in Exposure to Main Risks

Market Risk

(i) Interest Rate Risk

We are exposed to fluctuations in floating interest rate liabilities. We are exposed to U.S. dollar LIBOR and to Mexican peso TIIE. As of December 31, 2017, approximately 15.6 % of our total net debt outstanding consisted of floating rate debt.

Moreover, we invest in pesos and U.S. dollars in compliance with applicable internal regulations, through portfolios that have different purposes that seek an adequate return subject to risk parameters that reduce the probability of capital losses. The objective of the investments made through these portfolios is to meet our obligations payable in pesos and U.S. dollars.

The investments made through our portfolios are exposed to domestic and international interest rate risk and credit spread risk derived from government and corporate securities, and inflation risk arising from the relationship between UDIs and pesos. However, these risks are mitigated by established limits on exposure to market risk.

Interest Rate Swaps

Occasionally, for strategic reasons or in order to offset the expected inflows and outflows, we have entered into interest rate swaps. Under our interest rate swap agreements, we acquire the obligation to make payments based on a fixed interest rate and are entitled to receive floating interest rate payments based on LIBOR, TIIE or a rate referenced to or calculated from TIIE.

As of December 31, 2017, we were a party to four interest rate swap agreements denominated in U.S. dollars for an aggregate notional amount of U.S. $ 1,623.75 million at a weighted average fixed interest rate of 2.35% and a weighted average term of 7.3 years.

Similarly, in order to eliminate the volatility associated with variable interest rates of long-term financing operations, PMI NASA has executed interest rate swap agreements denominated in U.S. dollars for an

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outstanding aggregate notional amount of U.S. $ 71.94 million, at a weighted average fixed interest rate of 4.17% and a weighted average term of 4.41 years.

(ii) Exchange Rate Risk

Most of our revenues are denominated in U.S. dollars, a significant amount of which is derived from exports of crude oil and petroleum products, which are priced and payable in U.S. dollars. Moreover, our revenues from domestic sales of gasoline and diesel, net of IEPS Tax, tax duties, incentives, and other related taxes, as well as domestic sales of natural gas, LPG, petrochemicals and our byproducts are referenced to international U.S. dollar-denominated prices.

Our expenses related to hydrocarbon duties are calculated based on international U.S. dollar-denominated prices and the cost of hydrocarbon imports that we acquire for resale in Mexico or use in our facilities are indexed to international U.S. dollar-denominated prices. By contrast, our capital expenditure and operating expenses are established in pesos.

As a result of this cash flow structure, the depreciation of the peso against the U.S. dollar increases our financial balance. The appreciation of the peso relative to the U.S. dollar has the opposite effect. We manage this risk without the need for hedging instruments, because the impact on our revenues of fluctuations in the exchange rate between the U.S. dollar and the peso is offset in whole or in part by its impact on our obligations.

Cross-Currency Swaps

We prioritize debt issuances denominated in U.S. dollars; nonetheless, this is not always achievable and hence non-U.S. dollar-denominated debt issued in international currencies is hedged through DFIs, either with swaps to convert the debt into U.S. dollars or through other DFIs to mitigate our exchange rate risk exposure. The rest of the debt is denominated in pesos or in UDIs, for which most of the debt denominated in UDIs has been converted into pesos through DFIs in order to eliminate the inflationary risk exposure.

As a consequence of the above, our debt issued in international currencies other than U.S. dollars has exchange rate risk mitigation strategies. Through these strategies, we have further sought to reduce our cost of funding by leaving, in some cases, part of this exchange rate exposure unhedged when assessed appropriate.

The underlying currencies of our DFIs are the euro, Swiss franc, Japanese yen, Pound sterling and Australian dollar against the U.S. dollar and UDIs against the peso.

In 2017, we entered into various cross-currency swaps to hedge inflation risk arising from debt obligations denominated in UDIs for an aggregate notional amount of Ps. 6,291.97 million. During 2016, we entered into the same kind of instruments to hedge currency risk arising from debt obligations denominated in euros and Swiss francs, for an aggregate notional amount of U.S. $3,459.2 million and the inflation risk arising from debt denominated in UDIs, for an aggregate notional amount of Ps. 1,077.1 million.

Most of our cross-currency swaps are plain vanilla except for one swap entered into in 2004 to hedge our exposure to euros, which expired in 2016. This swap was referred to as an “extinguishing swap” and was obtained in order to hedge long-term obligations. The main characteristic of extinguishing swaps is that these DFIs terminate upon the occurrence of any of the credit default events specified in the DFI contract confirmation, without any payment obligation by either party. This swap had a notional amount of U.S. $1,146.4 million.

Moreover, in 2017 we entered into, without cost, three options structures called “Seagull Option” to hedge the notional risk of three debt issues in euros for an aggregate notional amount of € 4,250 million. These structures protect the short exposure in euros against an appreciation of the euro versus the U.S. dollar in a specific range, and recognize a benefit if the euro depreciates up to a certain exchange rate, for each debt issue. In order to mitigate the exchange rate risk caused by the coupons of these issues we entered into only coupon swaps.

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Additionally, we entered into, without cost, a structure which is composed of a cross-currency swap and the sale of a call option, in order to hedge the notional risk of a debt issue in Pounds sterling for £450 million, guaranteeing complete protection up to a certain exchange rate and partial protection above that level.

In 2016, we entered into, without cost, an options structure called “Seagull Option” in order to cover the notional risk of a debt issue in Japanese yen for ¥80,000 million, keeping the coupons in the original currency (0.5% annual coupon rate). This structure protects the short exposure in Japanese yen against an appreciation of the Japanese yen versus the U.S. dollar in a specific range, and recognizes a benefit if the Japanese yen depreciates up to a certain exchange rate.

We recorded a total net foreign exchange gain of Ps. 23,184.1 million for the year ended December 31, 2017 and a total net foreign exchange loss of Ps. 254,012.7 million and Ps. 154,765.6 million for the years ended December 31, 2016 and 2015, respectively. These gains and losses include unrealized foreign exchange gains associated with debt of Ps. 16,685.4 million for the year ended December 31, 2017 and unrealized foreign exchange loss associated with debt of Ps. 243,182.8 million and Ps. 152,554.5 million for the years ended December 31, 2016 and 2015, respectively. The appreciation of the peso caused a total net foreign exchange gain in 2017 because a significant portion of our debt, 89.4% (principal only) as of December 31, 2017, is denominated in foreign currency. Unrealized foreign exchange gains and losses do not impact our cash flows. Due to the cash flow structure described above, the depreciation of the peso relative to the U.S. dollar does not affect our ability to meet U.S. dollar-denominated financial obligations and it improves our ability to meet peso-denominated financial obligations. On the other hand, the appreciation of the peso relative to the U.S. dollar may increase our peso-denominated debt service costs on a U.S. dollar basis. Our foreign exchange gain in 2017 was due to the appreciation of the peso, from Ps. 20.6640 = U.S. $1.00 on December 31, 2016 to Ps. 19.7867 = U.S. $1.00 on December 31, 2017. Our foreign exchange loss in 2016 was due to the depreciation of the peso, from Ps. 17.2065 = U.S. $1.00 on December 31, 2015 to Ps. 20.6640 = U.S. $1.00 on December 31, 2016. Our foreign exchange loss in 2015 was due to the depreciation of the peso, from Ps. 14.7180 = U.S. $1.00 on December 31, 2014 to Ps. 17.20650 = U.S. $1.00 on December 31, 2015.

Certain of the PMI subsidiaries face market risks generated by fluctuations in foreign exchange rates. In order to mitigate these risks, the boards of directors of several of these companies have authorized a policy which stipulates that no more than 5% of a company’s total financial assets may be denominated in a currency other than its functional currency, unless the company owes a duty or expected payment in a currency other than its functional one. Accordingly, certain of the PMI subsidiaries will, from time to time, enter into DFIs in order to mitigate the risk associated with financing operations denominated in currencies other than a company’s functional currency.

Finally, a significant amount of PMI Trading’s income and expenses, including the cost of sales and related sales costs, is derived from the trade of refined products, petrochemicals and gas liquids to our subsidiaries and third parties, whose prices are determined and are payable in U.S. dollars. PMI Trading’s exposure to foreign currency risk results primarily from the need to fund tax payments denominated in domestic currency, as well as from certain related sales costs denominated in domestic currency.

PMI Trading believes it can adequately manage the risk created by the payment of taxes in domestic currency without the need to enter into hedging instruments because the exposure to this risk is marginal relative to the total flows of U.S. dollar. In addition, in the event that a potential foreign exchange risk arises in connection with a commercial transaction, PMI Trading may implement risk mitigation measures by entering into DFIs.

(iii) Hydrocarbon Price Risk

We periodically assess our revenues and expenditures structure in order to identify the main market risk factors that our cash flows are exposed to in connection with international hydrocarbon prices. Based on this

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assessment, we monitor our exposure to the most significant risk factors and quantify their impact on our financial balance.

Our exports and domestic sales are directly or indirectly related to international hydrocarbon prices. Therefore, we are exposed to fluctuations in these prices. In terms of crude oil and natural gas, part of this risk is transferred to the Mexican Government under our current fiscal regime.

We continuously evaluate the implementation of risk mitigation strategies, including those involving the use of DFIs, while taking into account operational and economic constraints.

Our exposure to hydrocarbon prices is partly mitigated by natural hedges between our inflows and outflows.

Since 2016, as a result of the changes in our fiscal regime, our sensitivity to crude oil prices has decreased. Nonetheless, we worked on hedging strategies for the following years in order to reduce our exposure to potential drops in the crude oil price.

Commodity Derivatives

In April 2017, we entered into a crude oil hedge to partially protect our cash flows from a decrease in the Mexican crude oil basket price below that established in the Federal Revenue Law. We hedged 409 thousand barrels per day from May to December 2017 for U.S. $133.5 million. As a result of this strategy, we had an income of U.S. $205.7 million.

During the fourth quarter of 2017, we entered into a crude oil hedge to partially protect our cash flows for the fiscal year 2018, from a decrease in the Mexican crude oil basket price below that established in the 2018 Federal Revenue Law. We hedged 440 thousand barrels per day from January to December 2018 for U.S. $449.9 million.

In addition to supplying natural gas, Pemex Industrial Transformation offers DFIs to its domestic customers in order to provide them with support to mitigate the risk associated with the volatility of natural gas prices. Until 2016, Pemex Industrial Transformation entered into DFIs with Mex Gas Supply, S.L. under the opposite position to those DFIs offered to its customers in order to mitigate the market risk it bears under such offered DFIs. Mex Gas Supply, S.L. then transferred the related price risk derived from the DFI position held with Pemex Industrial Transformation to international financial counterparties by entering into these opposite position DFIs with such parties. As of 2017, Pemex Industrial Transformation must enter into DFIs with Petróleos Mexicanos under the opposite position to those DFIs offered to its customers, thereby replacing Mex Gas Supply, S.L. However, as of December 31, 2017, no DFIs had been carried out under this mechanism. Through these mechanisms, Pemex Industrial Transformation maintains a negligible or even null exposure to market risk. These portfolios have VaR and CaR limits in order to limit market risk exposure.

PMI Trading faces market risk generated by the terms of the purchase and sale of refined products and natural gas liquids, as well as the volatility of oil prices. Accordingly, it frequently enters into DFIs in order to mitigate this risk, thereby reducing the volatility of its financial results.

In accordance with the risk management regulatory framework that PMI Trading has implemented, VaR and the change in profit and loss by portfolio are calculated daily and compared to the maximum applicable limits in order to implement risk mitigation mechanisms as necessary.

(iv) Risks Related to the Portfolio of Third-Party Shares

During 2017, PMI subsidiaries liquidated the total shareholding in Repsol, S.A. (Repsol), which was 23,416,219 shares. As a result, as of December 31, 2017, we do not hold any third-party shares of companies that do not report on the financial markets and, therefore, we do not hold any related DFIs.

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Counterparty or Credit Risk

When the fair value of a DFI is favorable to us, we face the risk that the counterparty will not be able to meet its obligations. We monitor our counterparties’ creditworthiness and calculate the credit risk exposure for our DFIs. As a risk mitigation strategy, we only enter into DFIs with major financial institutions with a minimum credit rating of BBB-. These ratings are issued and revised periodically by risk rating agencies. Furthermore, we seek to maintain a diversified portfolio of counterparties.

In order to estimate our credit risk exposure to each financial counterparty, the potential future exposure is calculated by projecting the risk factors used in the valuation of each DFI in order to estimate the MtM value for different periods, taking into account any credit risk mitigation provisions.

Moreover, we have entered into various long-term cross-currency swaps agreements with “recouponing” provisions (pursuant to which the payments on the swaps are adjusted when the MtM exceeds the relevant threshold specified in the swap), thereby limiting our exposure with our counterparties to a specific threshold amount. The specified thresholds were reached in three cross-currency swaps from the first to the fourth quarter of 2017, which were used to hedge the exchange rate exposure to the euro and in five cross-currency swaps during 2016, which were used to hedge the exchange rate exposure to the Pound sterling. This resulted in the cash settlement of such swaps and the resetting of swap terms to return their mark-to-market value to zero. During 2017, we did not enter into any cross-currency swap with these characteristics.

In addition, during 2016 we entered into long-term DFIs with mandatory early termination clauses (pursuant to which, at a given date, and irrespective of the then current MtM, the DFI will terminate and settle at the corresponding MtM, and we can either enter into a new DFI with the same counterparty or a new counterparty) which reduces the credit risk generated by the term of the DFI by bounding it to a specific date. As of December 31, 2017, we have entered into three euro swaps and two Japanese yen Seagull Option structures, with termination clauses in 2018 and 2021, respectively.

According to IFRS 13 “Fair Value Measurement,” the fair value or MtM value of DFIs must reflect the creditworthiness of the parties. Consequently, the fair value of a DFI takes into account the risk that either party may default on its obligation. In accordance with market best practices, we apply the credit value adjustment (“CVA”) method to calculate the fair value of our DFIs.

For each DFI, the CVA is calculated by determining the difference between the MtM and the estimated MtM adjusted for credit risk. In determining the credit risk, the CVA method takes into account the current market perception about the credit risk of both counterparties, using the following inputs: (a) the MtM projection for each payment date based on forward yield curves; (b) the implied default probability obtained from both us and the counterparty’s credit default swaps, at each payment date; and (c) the default recovery rates of each counterparty.

Furthermore, by means of its credit guidelines for DFI operations, Pemex Industrial Transformation has significantly reduced its credit risk exposure related to the DFIs offered to its customers to assist them in mitigating the risk associated with the price volatility of natural gas.

In order to qualify for these DFIs, Pemex Industrial Transformation’s customers must be party to a current natural gas supply contract and sign a domestic master derivative agreement.

Additionally, beginning on October 2, 2009, DFIs with these customers must be initially secured by cash deposits, letters of credit or other collateral provisions, as required. In accordance with these guidelines, in the event that a client does not meet its payment obligations, DFIs related to this client are terminated, rights to collateral are exercised and, if the collateral is insufficient to cover the fair value, natural gas supply is suspended until the payment is made.

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On August 20, 2014, certain amendments to the credit guidelines were enacted which allowed Pemex-Gas and Petrochemicals, and now Pemex Industrial Transformation, to offer to its clients with an adequate credit rating, based on an internal financial and credit assessment, DFIs with an exemption from collateral requirements up to certain amount through a credit line approved by the credit committee. Moreover, if the credit line is insufficient to cover each client’s exposure, the client is obligated to deposit collateral. If a client suffers an event of default, DFIs related to this client are terminated early and natural gas supply is suspended until the payment is made.

PMI Trading’s credit risk associated with DFI transactions is minimized through the use of futures and standardized instruments that are cleared through CME-ClearPort.

Accounting Standards Applied and the Impact on Results

We enter into derivatives transactions with the sole purpose of hedging financial risks related to our operations, firm commitments, planned transactions and assets and liabilities recorded on our statement of financial position. Nonetheless, some of these transactions do not qualify for hedge accounting treatment because they do not meet the requirements of the accounting standards for being designated as hedges. They are therefore recorded in the financial statements as non-hedge instruments or as instruments entered into for trading purposes, despite the fact that their cash flows are offset by the cash flows of the positions (assets or liabilities) to which they are related. As a result, the changes in their fair value are recognized in the “Derivative financial instruments (cost) income—net” line item in the consolidated statement of comprehensive income.

As of December 31, 2017 and 2016, the net fair value of our DFIs, including both DFIs that have not reached maturity and those that have reached maturity but have not been settled, recognized in our consolidated statement of financial position, was Ps. 12,367.5 million and Ps. (26,010.5) million, respectively. As of December 31, 2017 and 2016, we did not have any DFIs designated as hedges. See Note 16 to our consolidated financial statements included herein.

For the year ended December 31, 2017, we recognized a net gain of Ps. 25,338.3 million and for the years ended December 31, 2016 and 2015, we recognized a net loss of Ps. 14,001.0 million and Ps. 21,449.9 million, respectively, in the “Derivative financial instruments (cost) income, net” line item with respect to DFIs treated as instruments entered into for trading purposes.

According to established accounting policies, we have analyzed the different contracts that we have entered into and have determined that according to the terms thereof none of these agreements meet the criteria to be classified as embedded derivatives. Accordingly, as of December 31, 2017 and 2016, we did not recognize any embedded derivatives (foreign currency or index).

QUANTITATIVE DISCLOSURE

Fair Value

The following tables show our cash flow maturities as well as the fair value of our debt and DFI portfolios as of December 31, 2017. It should be noted that:

• For debt obligations, these tables present principal cash flow and the weighted average interest rates for fixed rate debt.

• For interest rate swaps, cross-currency swaps, currency options and currency forwards, these tables present notional amounts and weighted average interest rates by expected (contractual) maturity dates.

• Weighted average variable rates are based on implied forward rates obtained from the interbank market yield curve at the reporting date.

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• For natural gas DFIs, volumes are presented in millions of British thermal units (MMBtu), and fixed average and strike prices are presented in U.S. dollars per MMBtu.

• For crude oil, volumes are presented in millions of barrels, and fixed average and strike prices are presented in U.S. dollars per barrel.

• A DFI’s fair value includes CVA and is calculated based on market quotes obtained from market sources such as Bloomberg. Forward curves and implied volatilities for natural gas and crude oil are supplied by the Kiodex Risk Workbench platform.

• For PMI Trading, the prices used in commercial transactions and DFIs are published by reputable sources that are widely used in international markets, such as CME-NYMEX, Platts and Argus, among others.

• Fair value is calculated internally, either by discounting cash flows with the corresponding zero-coupon yield curve in the original currency, or through other standard methodologies commonly used in financial markets for specific instruments.

• For all instruments, the tables are based on the contract terms in order to determine the future cash flows that are categorized by expected maturity dates.

This information is presented in thousands of pesos (except as noted).

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Quantitative Disclosure of Debt Cash Flow’s Maturities as of December 31, 2017⁽¹⁾

	Year of expected maturity date										2023 thereafter		Total carrying  value			Fair value
	2018		2019		2020		2021		2022
Liabilities
Outstanding debt
Fixed rate (U.S. dollars)		Ps 53,465,817		Ps 59,498,256		Ps 60,290,621		Ps 95,232,448		Ps 84,076,050		Ps 808,836,547		Ps 1,161,399,739			1,213,404,769
Average interest rate (%)														5.7747	%
Fixed rate (Japanese yen)		—		—		—		—		—		19,296,607		19,296,607			18,040,398
Average interest rate (%)														1.3485	%
Fixed rate (Pounds)		—		—		—		—		9,345,839		11,952,816		21,298,655			24,381,394
Average interest rate (%)														5.7246	%
Fixed rate (pesos)		—		—		10,033,017		20,376,655		1,999,098		88,349,072		120,757,842			171,683,692
Average interest rate (%)														7.4876	%
Fixed rate (UDIs)		—		18,477,076		4,764,175		3,874,313		—		30,081,647		57,197,211			56,536,905
Average interest rate (%)														2.7458	%
Fixed rate (euros)		1,043		32,042,196		30,801,894		41,508,857		23,655,950		171,255,634		299,265,574			330,573,998
Average interest rate (%)														3.6736	%
Fixed rate (Swiss Francs)		4,565,075		6,088,686		12,149,953		3,046,567		—		—		25,850,281			26,957,785
Average interest rate (%)														1.8387	%
Fixed rate (Australian dollars)		—		—		—		—		—		—		—			—
Average interest rate (%)		—		—		—		—		—		—		—			—
Total fixed rate debt		58,031,935		116,106,214		118,039,660		164,038,840		119,076,937		1,129,772,323		1,705,065,909			1,841,578,940
Variable rate (U.S. dollars)		58,364,536		15,302,101		62,289,546		12,809,666		31,289,725		18,379,557		198,435,131			206,254,219
Variable rate (Japanese yen)		—		—		11,244,800		—		—		—		11,244,800			11,361,079
Variable rate (pesos)		8,734,371		27,995,083		18,341,742		8,459,163		8,394,483		19,125,764		91,050,606			94,188,981
Total variable rate debt		67,098,907		43,297,184		91,876,088		21,268,829		39,684,208		37,505,321		300,730,537			311,804,280
Total debt		125,130,842		159,403,398		209,915,748		185,307,669		158,761,145		1,167,277,644		2,005,796,446			2,153,383,220

Note: Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2017 of: Ps. 19.7867 = U.S. $1.00; Ps. 0.1757 = 1.00 Japanese yen; Ps. 26.7724 = 1.00 Pound sterling; Ps. $ 5.934551 = 1.00 UDI; Ps. 23.7549 = 1.00 euro; Ps. 20.2992 = 1.00 Swiss Franc; and Ps. 15.4752 = 1.00 Australian dollar.

Source: PEMEX

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Quantitative Disclosure of Cash Flow’s Maturities from Derivative Financial Instruments Held or Issued for Purposes Other than Trading as of December 31, 2017⁽¹⁾⁽²⁾

	Year of expected maturity date																		Total Notional Amount		Fair Value(3)
	2018			2019			2020			2021			2022			2023 Thereafter
Hedging instruments(2)(4)
Interest rate DFIs
Interest rate swaps (U.S. dollars)
Variable to fixed		Ps. 4,704,170			Ps. 4,717,321			Ps. 4,730,857			Ps. 4,686,396			Ps 4,570,070			Ps 10,143,209			Ps. 33,552,022		Ps. 388,851
Average pay rate		3.16	%		3.18	%		3.20	%		3.22	%		3.26	%		3.48	%		N.A.		N.A.
Average receive rate		3.19	%		3.44	%		3.69	%		3.81	%		3.95	%		4.48	%		N.A.		N.A.
Interest rate swaps (pesos)
Variable to fixed		—			—			—			—			—			—			—		—
Average pay rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Average receive rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Currency DFIs
Cross-currency swaps
Receive euros/Pay U.S. dollars		—			29,898,198			28,719,208			36,902,690			21,302,856			161,617,172			278,440,124		19,065,727
Receive Japanese yen/Pay U.S. dollars		—			—			13,039,563			—			—			4,775,551			17,815,114		(1,670,533	)
Receive Pounds sterling/Pay U.S. dollars		—			—			—			—			10,310,216			11,706,999			22,017,215		1,151,096
Receive UDI/ Pay pesos		—			23,740,341			7,292,520			3,000,000			—			20,605,166			54,638,028		(4,720,592	)
Receive Swiss francs/Pay U.S. dollars		4,535,474			6,501,082			11,548,658			2,994,374			—			—			25,579,588		400,316
Receive Australian dollars/Pay U.S. dollars		—			—			—			—			—			—			—		—
Currency Options
Buy Put, Sell Put and sell Call on Japanese yen		—			—			—			—			—			14,046,320			14,046,320		48,715
Buy call, Sell call and Sell put on euros		—			—			—			—			41,567,998			59,382,855			100,950,853		4,919,444
Sell Call on Pound sterling		—			—			—			—			—			12,031,728			12,031,728		(239,626	)
Curency Forward
Receive U.S. dollars / Pay pesos		59,360,100			—			—			—			—			—			59,360,100		(2,006,461	)

N.A. = not applicable.

Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2017 of: Ps. 19.7867 = U.S. $1.00 and Ps. 23.7549 = 1.00 euro.

(2) Our management uses these DFIs to hedge market risk; however, these DFIs do not qualify for accounting purposes as hedges and are recorded in the financial statements as entered into for trading purposes.

(3) Positive numbers represent a favorable fair value to us.

(4) PMI’s risk management policies and procedures establish that DFIs should be used only for hedging purposes; however DFIs are not recorded as hedges for accounting purposes.

Source: PEMEX

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Quantitative Disclosure of Cash Flow’s Maturities from Derivative Financial Instruments (Natural Gas) Held or Issued for Purposes other than Trading as of December 31, 2017⁽¹⁾⁽²⁾

	2018			2019			2020		2021		2022		2023 Thereafter		Total Volume			Fair Value(2)
	(in MMBtu, except that average fixed and strike prices are in U.S. $ per MMBtu)																	(in thousands of nominal pesos)
Derivatives entered into with Customers of Pemex Industrial Transformation
Short
European Call Option		(270,200	)		(13,750	)		—		—		—		—		(283,950	)		(396.97	)
Average strike price		3.29			3.81			—		—		—		—		3.31
Variable to Fixed Swap(3)		(721,896	)		(101,864	)		—		—		—		—		(823,760	)		6,934.34
Average fixed price		3.19			3.08			—		—		—		—		3.17
Long
European Call Option		—			—			—		—		—		—		—			—
Average strike price		—			—			—		—		—		—		—			—
Derivatives entered into with Third Parties to Offset Transactions entered into with Customers
Short
European Call Option		—			—			—		—		—		—		—			—
Average strike price		—			—			—		—		—		—		—			—
Long
European Call Option		270,200			13,750			—		—		—		—		283,950			397.56
Average strike price		3.29			3.81			—		—		—		—		3.31
Variable to Fixed Swap(4)		721,896			101,864			—		—		—		—		823,760			(6,113.56	)
Average fixed price		3.13			3.03			—		—		—		—		3.12

Notes: Numbers may not total due to rounding.

(1) The information in this table has been calculated using the exchange rate at December 31, 2017 of: Ps. 19.7867 = U.S. $1.00.

(2) Positive numbers represent a favorable fair value to us.

(3) Under short variable to fixed swaps entered into with customers of Pemex Industrial Transformation, we will pay a variable price and receive the fixed price specified in the contract.

(4) Under long variable to fixed swaps entered into with customers of Pemex Industrial Transformation, we will pay the fixed price specified in the contract and receive a variable price.

Source: Pemex Industrial Transformation

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Quantitative Disclosure of Cash Flows’ Maturities from Derivative Financial Instruments (Petroleum Products) Held or Issued for Purposes other than Trading as of December 31, 2017⁽¹⁾

	2018		2019		2020		2021		2022		2023 Thereafter		Total Volume		Fair Value(2)
			(in thousands of barrels)												(in thousands of nominal pesos)
Hedging Instruments
Exchange-traded futures(3) (5)		2.1		—		—		—		—		—		2.1		(141,693	)
Exchange-traded swaps(4) (5)		1.3		—		—		—		—		—		1.3		(99,680	)

Note: Numbers may not total due to rounding.

(1) The information in this table has been calculated using the exchange rate at December 31, 2017 of: Ps. 19.7867 = U.S. $1.00.

(2) Positive numbers represent a favorable fair value to PMI Trading.

(3) Net position.

(4) Swaps registered in CME ClearPort are included in these figures.

(5) The balance of these financial instruments is recognized as cash and cash equivalents. PMI Trading considered these financial assets to be fully liquid.

Source: P.M.I. Trading, Ltd.

Sensitivity Analysis

We have entered into DFIs with the purpose to completely mitigate the market risk for specific flows or predetermined volumes associated with our operations. Our DFIs have the same characteristics (e.g. underlying assets, payment dates, amounts, or volumes) as the hedged position, but with the opposite exposure to the market risk factors. As a result of these mitigation strategies, we have a negligible sensitivity to the hedged market risk factors. See Note 16 from our consolidated financial statements included herein.

As discussed above, because our hedges are cash flow hedges, their effectiveness is maintained regardless of variations in the underlying assets or reference variables since, through time, asset flows are fully offset by liabilities flows. Therefore, it is not necessary to measure or monitor the hedge effectiveness.

Natural gas DFIs that Pemex Industrial Transformation offers to its domestic customers are reported as transactions with trading purposes. However, such operations are fully compensated by the operations entered into with their financial counterparts through Petróleos Mexicanos, which replaced Mex Gas Supply, S.L. as of 2017. Through this mechanism (back-to-back), Pemex Industrial Transformation maintains a negligible or even null market risk exposure, so we do not consider it necessary to conduct either a sensitivity analysis or to measure or monitor the hedge effectiveness.

Other DFIs seek to hedge the changes in the price of the commercialized products, such that the DFIs’ underlying assets have correlations with the prices of the products involved in commercialization. PMI Trading estimates the Value at Risk (VaR) of these DFIs. Notably, DFIs of PMI Trading (all of them related to petroleum derivatives), are classified under cash and cash equivalents for accounting purposes due to their liquidity.

Item 12. Description of Securities Other than Equity Securities

Not applicable.

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PART II

Item 13. Defaults, Dividend Arrearages and Delinquencies

None.

Item 14. Material Modifications to the Rights of Security Holders and Use of Proceeds

None.

Item 15. Controls and Procedures

(a) Disclosure Controls and Procedures

We carried out an evaluation under the supervision and with the participation of our management, including our Director General (Chief Executive Officer or CEO) and our Director Corporativo de Finanzas (Chief Financial Officer or CFO), of the effectiveness of the design and operation of our disclosure controls and procedures as of December 31, 2017. There are inherent limitations to the effectiveness of any system of disclosure controls and procedures, including the possibility of human error and the circumvention or overriding of the controls and procedures. Accordingly, effective disclosure controls and procedures can provide only reasonable assurance of achieving their control objectives.

Based upon our evaluation, and because of the material weakness in internal control over financial reporting described below, our CEO and CFO concluded that our disclosure controls and procedures as of December 31, 2017 were not effective to provide reasonable assurance that information required to be disclosed in the reports we file and submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including to our CEO and CFO, as appropriate, to allow timely decisions regarding required disclosures.

(b) Management’s Annual Report on Internal Control over Financial Reporting

Management is responsible for establishing and maintaining adequate internal control over financial reporting. Our internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with IFRS. Our internal control over financial reporting includes those policies and procedures that:

(1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of our assets;

(2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with IFRS and with Item 18 of Form 20-F, and that our receipts and expenditures are being made only in accordance with authorizations of management and directors of the relevant entity; and

(3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on our financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness for future periods are subject to the risk that the related controls may become inadequate because of changes in conditions, or that the degree of compliance with policies or procedures may deteriorate.

We conducted an assessment of the effectiveness of our internal controls over financial reporting as of December 31, 2017. In making this assessment, management used the criteria set for in the “Internal Control—

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Integrated Framework” published by the Committee of Sponsoring Organizations of the Treadway Commission in 2013, supplemented for information technologies with the guidelines suggested by IT Control Objectives for Sarbanes-Oxley (3rd Edition), published by the Information Systems Audit and Control Association, in effect as of December 31, 2015. Management relied on Auditing Standard No. 2201 of the PCAOB in order to create an appropriate framework to evaluate the effectiveness of the design and operation of our internal control over financial reporting.

Management concluded that our internal control over financial reporting was not effective as of December 31, 2017. Based on our assessment and criteria, management concluded that a material weakness existed in connection with our internal control over financial reporting as of December 31, 2017 that affected our calculation of recognized deferred taxes at the time that we filed our unaudited consolidated financial statements with the Mexican Stock Exchange. Due to the lack of consistency in the reporting of, and the failure to timely determine, the amounts of the variables used in the calculation of deferred taxes, and the ineffectiveness of controls to review and authorize such calculation, we were unable to ascertain with reasonable assurance the amount of deferred taxes for the fiscal year ended December 31, 2017. In addition, the calculation of deferred taxes included in our unaudited consolidated financial statements did not take into account new regulations issued by the Ministry of Finance and Public Credit. On August 18, 2017, the Ministry of Finance and Public Credit published a decree that increased the amount that could be deducted for investments, costs and expenses when calculating the Derecho por la Utilidad Compartida (“Profit-Sharing Duty”). On November 30, 2017, the Ministry of Finance and Public Credit issued an additional decree that revised the methodology for calculating the value of hydrocarbons, which has an effect on the determination of the volumes and prices of crude oil, gas and condensates used to calculate the Profit-Sharing Duty. These new regulations, which we did not reflect at the time that we presented our unaudited consolidated financial statements to the Mexican Stock Exchange, had an impact on the calculation of deferred taxes.

As a result, our unaudited consolidated financial statements as of and for the year ended December 31, 2017 reflected a net loss in the amount of Ps. 333.4 billion. In connection with the preparation of our audited consolidated financial statements, we were able to determine the definitive amounts of the variables used in the calculation of deferred taxes and performed the calculation in accordance with the new regulations. As a result, we reported a net loss of Ps. 280.9 billion, or Ps. 52.5 billion less than the Ps. 333.4 billion we reported in our unaudited consolidated financial statements. This favorable effect was primarily due to the Ps. 37.2 billion increase in deferred taxes resulting from the implementation of the new regulations issued by the Ministry of Finance and Public Credit.

Although the effect is favorable, the difference between the deferred taxes disclosed in our unaudited consolidated financial statements and our audited consolidated financial statements as of and for the year ended December 31, 2017—an amount equal to Ps. 54.3 billion—is material and reflects a failure of our internal controls to include a mechanism to ensure that our calculation of deferred taxes is accurate and that the disclosure of our unaudited financial results in respect of deferred taxes is consistent with the disclosure of our audited results.

In response to the material weakness described above, we are in the process of executing a remediation plan that includes the following actions:

1. Comprehensive review of the process for consolidating, reviewing and finalizing the financial statements of Petróleos Mexicanos and its subsidiary entities.

2. Automation of our information systems used to calculate deferred taxes, formalization of access control roles and segregation of the relevant duties, and the preparation, supervision and authorization of deferred tax calculations.

3. Implementation of periodic, rather than annual, calculations of the amount of deferred taxes to be recognized in the financial statements of Petróleos Mexicanos and its subsidiary entities.

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4. Update of the relevant internal procedures to ensure the responsibility and oversight of the specific operational areas involved in reporting the underlying information necessary to calculate deferred taxes.

5. Strengthening and periodic monitoring of the existing internal controls in order to ensure the timely and accurate calculation of deferred taxes and to provide our internal control unit time to correct any failure in the internal controls.

We did report a material weakness in internal control over financial reporting in our annual report on Form 20-F for the years ended December 31, 2015 and 2016, both of which related to the calculation of impairment of our wells, pipelines, properties, plant and equipment.

For the year ended December 31, 2015, we had not, at the relevant time, established an effective design of processes and procedures to effectively respond to the nature and magnitude of the changes in the economic landscape at such time. In particular, the sharp decline in the price of crude oil in the fourth quarter of 2015 triggered the need to test carrying amounts of our wells, pipelines, properties, plant and equipment for impairment. In performing the tests, the discount rates used were lower than those required by IFRS and those used by peers in the sector and categorized our entire refinery system as a single cash generating unit instead of viewing each refinery as an independent cash-generating unit in order to determine impairment charges with respect to our wells, pipelines, properties, plant and equipment, as required by IFRS. That resulted in an estimation of recoverable amounts of assets that did not accurately reflect operating and economic conditions as of the date of our consolidated financial statements. For the reasons set forth above, those unaudited financial statements reflected only a Ps. 229.1 billion impairment of wells, pipelines, properties, plant and equipment in 2015, Ps. 248.8 billion less than the actual impairment of Ps. 477.9 billion. In addition, at that time, our internal controls did not provide a mechanism that enabled us to ensure that our disclosure regarding our impairment evaluation and our liquidity condition complied with IFRS. In our unaudited financial statements as of and for the fiscal year ended December 31, 2015, we did not appropriately disclose the assumptions for the computation of the impairment, the uncertainties about the estimates used to calculate impairment and the relevant assets impacted by the impairment and issues related to significant doubt about our ability to continue operating as a going concern in accordance with IFRS.

For the year ended December 31, 2016, we incorrectly assumed, for purposes of the impairment analysis of our exploration and production cash generating units, the economic landscape related to the two-year life-of-field for those fields assigned to Petróleos Mexicanos on temporary basis pursuant to Round Zero rather than 25-year life-of-field allowed by the CNH. As a result, our unaudited consolidated financial statements as of and for the year ended December 31, 2016 only reflected a net reversal of impairment in the amount of Ps. 246.3 billion. In connection with the preparation of our audited consolidated financial statements as of and for the year ended December 31, 2016, we applied the 25-year life-of-field assumption allowed by the CNH which, combined with the certified reserves data, resulted in a net reversal of impairment in the amount of Ps. 331.3 billion, a difference, while favorable, of Ps. 85.0 billion.

In response to the material weaknesses described above, we executed remediation plans, with oversight of our audit committee that took, among others, the following actions:

1. We strengthened our controls focused on generating adequate and timely policies related to updated regulatory criteria that may affect our financial reporting.

2. We strengthened our procedures relating to compliance with general policies and designed procedures to ensure that regulatory criteria, legal aspects and business rules are disseminated and implemented in a timely manner.

3. We improved our internal procedures to appropriately prepare documentation that keeps track of the process for impairment calculations.

4. We improved our procedures for the definition of the criteria involved in calculating the impairment of assets in the oil and gas industry, such as, among others, the identification of cash generating units, discount

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rates, hydrocarbon prices and exchange rates in order to accurately reflect the operating and economic conditions at the time of our calculations.

5. We updated our oversight and monitoring program, as part of which we submit quarterly reports to our audit committee to keep track of the progress of the implemented actions.

We submitted the “General Policies and Procedures for the Determination of the Impairment Value of Assets in Petróleos Mexicanos and its Subsidiary Productive Enterprises” to the Regulatory Improvement Committee (COMERI), which describes our policy proposals to comply with the International Accounting Standard (NIC) 36. The proposal is currently under review by COMERI.

(c) Attestation Report of the Independent Registered Public Accounting Firm

Not applicable.

(d) Changes in Internal Control over Financial Reporting

As discussed above, during 2017, we completed the design, update and strengthening of controls, procedures and assessment methodology in order to appropriately calculate the impairment of our assets and to ensure that we respond promptly to changes in regulatory criteria and business rules. We also continued to execute on the changes made to our internal controls in 2016 in order to ensure that we effectively respond to the nature and magnitude of the changes in the economic landscape.

Except for these changes, there has been no change in our internal control over financial reporting during 2017 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

Item 16A. Audit Committee Financial Expert

Ms. Maria Teresa Fernández Labardini, member of the Audit Committee of Petróleos Mexicanos, qualifies as an “audit committee financial expert” within the meaning of this Item 16A, and is independent, as defined in Rule 10A-3 under the Exchange Act.

Item 16B. Code of Ethics

In accordance with the Petróleos Mexicanos Law, on November 2016, we issued the Código de Ética para Petróleos Mexicanos, sus empresas productivas subsidiarias y empresas filiales (Code of Ethics for Petróleos Mexicanos, its productive subsidiary entities and affiliates, or the Code of Ethics), a code of ethics as defined in Item 16B of Form 20-F under the Exchange Act. Our Code of Ethics applies to the members of the Boards Directors of Petróleos Mexicanos and the subsidiary entities and all of our employees, including our Director General, our Chief Financial Officer, our chief accounting officer and all other employees performing similar functions, as well as other individuals and companies whose actions may affect our reputation. The Code of Ethics defines values such as respect, non-discrimination, honesty, loyalty, responsibility, legality, impartiality and integrity, among others, that we expect will help us achieve our goals and which should be reflected in the daily behavior of employees of Petróleos Mexicanos.

Our Code of Ethics is available on our website at http://www.pemex.com. If we amend the provisions of our Code of Ethics or if we grant any waiver of such provisions, we will disclose such amendment or waiver on our website at the same address.

On December 7, 2016, our Ethics Committee was formed to monitor the implementation and enforcement of the Code of Ethics. See “Item 4—Information on the Company—Business Overview—PEMEX Corporate Matters—Ethics Committee” for more information.

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On August 28, 2017, the new Código de Conducta de Petróleos Mexicanos, sus empresas productivas subsidiarias y, en su caso, empresas filiales (Code of Conduct of Petróleos Mexicanos, its productive subsidiary entities and, where applicable, affiliated companies, or the Code of Conduct) was published in the Official Gazette of the Federation. This Code of Conduct delineates behaviors expected of and banned for our employees, in accordance with the values established in the Code of Ethics approved by the Board of the Directors of Petróleos Mexicanos in November 2016.

On September 11, 2017, the Políticas y Lineamientos Anticorrupción para Petróleos Mexicanos, sus empresas productivas subsidiarias y, en su caso, Empresas Filiales (Anticorruption Policies and Guidelines for Petróleos Mexicanos, its productive subsidiary entities and, where applicable, affiliated companies) and the Políticas y Lineamientos para el desarrollo de la Debida Diligencia en Petróleos Mexicanos, sus empresas productivas subsidiarias y, en su caso, Empresas Filiales, en Materia de Ética e Integridad Corporativa (Policies and Guidelines to carry out Due Diligence in Petróleos Mexicanos, its productive subsidiary entities and, where applicable, affiliated companies, in Ethics and Corporate Integrity matters) became effective.

Additionally, we have now established an Ethics Line and made a telephone number available on our website, as a mechanism to provide advice to address questions on ethics and integrity issues within PEMEX and to facilitate receipt of complaints about possible violations to our Code of Ethics or our Code of Conduct. The information received will be channeled to the Ethics Committee and the appropriate areas authorized to investigate and, if applicable, pursue cases in accordance with the applicable laws.

We believe that the new regulations and mechanisms mentioned above, along with the legal framework applicable to PEMEX, will allow us to improve our ability to mitigate our exposure to bribery and corruption risks in our relationships with third parties. See “Item 3—Key Information—Risk Factors—Risk Factors Related to Our Operations—We are subject to Mexican and international anti-corruption, anti-bribery and anti-money laundering laws. Our failure to comply with these laws could result in penalties, which could harm our reputation, prevent us from obtaining governmental authorizations needed to carry out our operations and have an adverse effect on our business, results of operations and financial condition.”

Item 16C. Principal Accountant Fees and Services

In its meeting held on October 5, 2017, the Board of Directors of Petróleos Mexicanos appointed BDO Mexico as external auditor of Petróleos Mexicanos, its productive state-owned subsidiaries and subsidiary companies for the fiscal year 2017 based on the proposal of the Audit Committee. The Board of Directors of Petróleos Mexicanos also appointed KPMG Cárdenas Dosal, S.C. as external auditor of Petróleos Mexicanos, its productive state-owned subsidiaries and subsidiary companies for the fiscal year 2018 based on the proposal of the Audit Committee. See “Item 6—Directors, Senior Management and Employees—Audit Committee.”

Audit and Non-Audit Fees

The following table sets forth the aggregate fees billed to us for the fiscal years 2016 and 2017 by BDO Mexico, our independent registered public accounting firm for the years ended December 31, 2017 and 2016.

	Year ended December 31,
	2016		2017
	(in thousands of nominal pesos)
Audit fees		Ps. 46,587		Ps. 44,564
Audit-related fees		—		—
Tax Fees		—		—
All other fees		—		—
Total fees		Ps. 46,587		Ps. 44,564

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Audit fees in the table above are the aggregate fees billed by BDO Mexico for services provided in connection with the audits of our annual financial statements in each year, statutory filings and statutory audits, filings with financial regulators, regulatory filings, limited review of interim financial information, review of public filings of financial information and reviews of documents related to offerings of securities, as well as comfort and consent letters, and services provided in accordance with the instructions of the Audit Committee.

Audit Committee Approval Policies and Procedures

In accordance with the Petróleos Mexicanos Law, the Audit Committee nominates the external auditor for approval by the Board of Directors of Petróleos Mexicanos and issues an opinion regarding the external auditor’s report on our financial statements. See “Item 6—Directors, Senior Management and Employees—Audit Committee.”

On September 27, 2016, the Audit Committee issued criteria for the hiring of an external auditor for activities not related to its audit services in accordance with the Petróleos Mexicanos Law.

Item 16D. Exemptions from the Listing Standards for Audit Committees

Not applicable.

Item 16E. Purchases of Equity Securities by the Issuer and Affiliated Purchasers

Not applicable.

Item 16F. Change in Registrant’s Certifying Accountant

Not applicable.

Item 16G. Corporate Governance

Not applicable.

Item 16H. Mine Safety Disclosure

Not applicable.

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PART III

Item 17. Financial Statements

Not applicable.

Item 18. Financial Statements

See pages F-1 through F-151, incorporated herein by reference.

Item 19. Exhibits. Documents filed as exhibits to this Form 20-F:

1.1	Ley de Petróleos Mexicanos (Petróleos Mexicanos Law), effective October 7, 2014 (English translation) (previously filed as Exhibit 1.1 to Petróleos Mexicanos’ annual report on Form 20-F (File No. 0-99) on April 30, 2015 and incorporated by reference herein).
1.2	Reglamento de la Ley de Petróleos Mexicanos (Regulations to the Petróleos Mexicanos Law), effective November 1, 2014 and as amended as of February 9, 2015 (English translation) (previously filed as Exhibit 1.2 to Petróleos Mexicanos’ annual report on Form 20-F (File No. 0-99) on April 30, 2015 and incorporated by reference herein).
1.3	Acuerdo de Creación de la Empresa Productiva del Estado Subsidiaria de Petróleos Mexicanos, denominada Pemex Exploración y Producción (Creation Resolution of the Productive State-Owned Subsidiary of Petróleos Mexicanos, denominated Pemex Exploration and Production), effective June 1, 2015 (English translation) (previously filed as Exhibit 3.4 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-205763) on July 21, 2015 and incorporated by reference herein).
1.4	Acuerdo de Creación de la Empresa Productiva del Estado Subsidiaria de Petróleos Mexicanos, denominada Pemex Cogeneración y Servicios (Creation Resolution of the Productive State-Owned Subsidiary of Petróleos Mexicanos, denominated Pemex Cogeneration and Services), effective June 1, 2015 (English translation) (previously filed as Exhibit 3.5 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-205763) on July 21, 2015 and incorporated by reference herein).
1.5	Acuerdo de Creación de la Empresa Productiva del Estado Subsidiaria de Petróleos Mexicanos, denominada Pemex Perforación y Servicios (Creation Resolution of the Productive State-Owned Subsidiary of Petróleos Mexicanos, denominated Pemex Drilling and Services), effective August 1, 2015 (English translation) (previously filed as Exhibit 3.5 to Amendment No. 1 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-205763) on February 8, 2016 and incorporated by reference herein).
1.6	Acuerdo de Creación de la Empresa Productiva del Estado Subsidiaria de Petróleos Mexicanos, denominada Pemex Logística (Creation Resolution of the Productive State-Owned Subsidiary of Petróleos Mexicanos, denominated Pemex Logistics), effective October  1, 2015 (English translation) (previously filed as Exhibit 3.6 to Amendment No. 1 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No.  333-205763) on February 8, 2016 and incorporated by reference herein).
1.7	Acuerdo de Creación de la Empresa Productiva del Estado Subsidiaria de Petróleos Mexicanos, denominada Pemex Transformación Industrial (Creation Resolution of the Productive State-Owned Subsidiary of Petróleos Mexicanos, denominated Pemex Industrial Transformation), effective November 1, 2015 (English translation) (previously filed as Exhibit 3.7 to Amendment No. 1 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-205763) on February 8, 2016 and incorporated by reference herein).

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1.8	Adecuación al Acuerdo de Creación de la Empresa Productiva del Estado Subsidiaria de Petróleos Mexicanos, denominada Pemex Exploración y Producción (Amendment to Creation Resolution of the Productive State-Owned Subsidiary of Petróleos Mexicanos, denominated Pemex Exploration and Production), effective December 29, 2015 (English Translation) (previously filed as Exhibit 3.4 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-220721) on September 29, 2017 and incorporated by reference herein)
1.9	Adecuación al Acuerdo de Creación de la Empresa Productiva del Estado Subsidiaria de Petróleos Mexicanos, denominada Pemex Exploración y Producción (Amendment to Creation Resolution of the Productive State-Owned Subsidiary of Petróleos Mexicanos, denominated Pemex Exploration and Production), effective May 12, 2016 (English translation) (previously filed as Exhibit 3.4 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-213351) on November 30, 2016 and incorporated by reference herein)
2.1	Indenture, dated as of September 18, 1997, between Petróleos Mexicanos and Deutsche Bank Trust Company Americas (formerly known as Bankers Trust Company) (previously filed as Exhibit 4.1 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-7796) on October 17, 1997 and incorporated by reference herein).(P)
2.2	Indenture, dated as of August 7, 1998, between Petróleos Mexicanos and Deutsche Bank Trust Company Americas (formerly known as Bankers Trust Company) (previously filed as Exhibit 4.1 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-9310) on August 24, 1998 and incorporated by reference herein).(P)
2.3	Indenture, dated as of July 31, 2000, among the Pemex Project Funding Master Trust, Petróleos Mexicanos and Deutsche Bank Trust Company Americas (formerly known as Bankers Trust Company) (previously filed as Exhibit 2.5 to the Petróleos Mexicanos Annual Report on Form 20-F (File No. 0-99) on June 28, 2001 and incorporated by reference herein).(P)
2.4	First supplemental indenture dated as of September  30, 2009, between Petróleos Mexicanos and Deutsche Bank Trust Company Americas, to the indenture dated as of July 31, 2000 (previously filed as Exhibit 2.4 to the Petróleos Mexicanos Annual Report on Form 20-F (File No. 0-99) on June 29, 2010 and incorporated by reference herein).
2.5	Indenture, dated as of December  30, 2004, among the Pemex Project Funding Master Trust, Petróleos Mexicanos and Deutsche Bank Trust Company Americas (previously filed as Exhibit 2.7 to Petróleos Mexicanos’ Annual Report on Form 20-F (File No. 0-99) on June 30, 2005 and incorporated by reference herein).
2.6	First supplemental indenture dated as of September  30, 2009, between Petróleos Mexicanos and Deutsche Bank Trust Company Americas, to the indenture dated as of December 30, 2004 (previously filed as Exhibit 2.6 to the Petróleos Mexicanos Annual Report on Form 20-F (File No. 0-99) on June 29, 2010 and incorporated by reference herein).
2.7	Indenture, dated as of January  27, 2009, between Petróleos Mexicanos and Deutsche Bank Trust Company Americas (previously filed as Exhibit 2.5 to the Petróleos Mexicanos Annual Report on Form 20-F (File No. 0-99) on June 30, 2009 and incorporated by reference herein).
2.8	Fiscal Agency Agreement between Petróleos Mexicanos and Deutsche Bank Trust Company Americas (formerly known as Bankers Trust Company), dated as of June 16, 1993, and amended and restated as of February 26, 1998 (previously filed as Exhibit 3.1 to the Petróleos Mexicanos Annual Report on Form 20-F (File No. 0-99) on June 29, 2000 and incorporated by reference herein).(P)
2.9	Trust Agreement, dated as of November 10, 1998, among The Bank of New York, The Bank of New York (Delaware) and Petróleos Mexicanos (previously filed as Exhibit 3.1 to the Petróleos Mexicanos Annual Report on Form 20-F (File No. 0-99) on June 30, 1999 and incorporated by reference herein).(P)

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2.10	Amendment No. 1, dated as of November  17, 2004, to the Trust Agreement among The Bank of New York, The Bank of New York (Delaware) and Petróleos Mexicanos dated as of November 10, 1998 (previously filed as Exhibit 2.10 to the Petróleos Mexicanos Annual Report on Form 20-F (File No. 0-99) on June 30, 2005 and incorporated by reference herein).
2.11	Amendment No. 2, dated as of December  22, 2004, to the Trust Agreement among The Bank of New York, The Bank of New York (Delaware) and Petróleos Mexicanos dated as of November 10, 1998 (previously filed as Exhibit 2.11 to the Petróleos Mexicanos Annual Report on Form 20-F (File No. 0-99) on June 30, 2005 and incorporated by reference herein).
2.12	Amendment No. 3, dated as of August  17, 2006, to the Trust Agreement among The Bank of New York, The Bank of New York (Delaware) and Petróleos Mexicanos dated as of November  10, 1998 (previously filed as Exhibit 3.4 to the Petróleos Mexicanos Registration Statement on Form F-4/A (File No. 333-136674) on October  27, 2006 and incorporated by reference herein).
2.13	Assignment and Indemnity Agreement, dated as of November 10, 1998, among Petróleos Mexicanos, Pemex-Exploración y Producción, Pemex-Refinación, Pemex-Gas y Petroquímica Básica and the Pemex Project Funding Master Trust (previously filed as Exhibit 3.2 to the Petróleos Mexicanos Annual Report on Form 20-F (File No. 0-99) on June 30, 1999 and incorporated by reference herein).(P)
2.14	Amendment No. 1, dated as of August  17, 2006, to the Assignment and Indemnity Agreement among Petróleos Mexicanos, Pemex-Exploración y Producción, Pemex-Refinación, Pemex-Gas y Petroquímica Básica, Pemex-Petroquímica, and the Pemex Project Funding Master Trust dated as of November 10, 1998 (previously filed as Exhibit 4.7 to the Petróleos Mexicanos Registration Statement on Form F-4/A (File No. 333-136674-04) on October 27, 2006 and incorporated by reference herein).
2.15	Guaranty Agreement, dated July 29, 1996, among Petróleos Mexicanos, Pemex-Exploración y Producción, Pemex-Refinación and Pemex-Gas y Petroquímica Básica (previously filed as Exhibit 4.4 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-7796) on October 17, 1997 and incorporated by reference herein).(P)
2.16	Amendment Agreement dated as of June  24, 2014, between Petróleos Mexicanos and Deutsche Bank Trust Company Americas, amending the terms and conditions of the Petróleos Mexicanos 8.625% Bonds due 2023 issued pursuant to the Fiscal Agency Agreement between Petróleos Mexicanos and Deutsche Bank Trust Company (as amended and restated) (previously filed as Exhibit 4.9 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-198588) on September 5, 2014 and incorporated by reference herein).
2.17	First supplemental indenture dated as of June  24, 2014, between Petróleos Mexicanos and Deutsche Bank Trust Company Americas, to the indenture dated as of September 18, 1997 (previously filed as Exhibit 4.10 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-198588) on September 5, 2014 and incorporated by reference herein).
2.18	First supplemental indenture dated as of June  24, 2014, between Petróleos Mexicanos and Deutsche Bank Trust Company Americas, to the indenture dated as of August 7, 1998 (previously filed as Exhibit 4.11 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-198588) on September 5, 2014 and incorporated by reference herein).
2.19	Second supplemental indenture dated as of June  24, 2014, between Petróleos Mexicanos and Deutsche Bank Trust Company Americas, to the indenture dated as of July 31, 2000 (previously filed as Exhibit 4.12 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-198588) on September 5, 2014 and incorporated by reference herein).
2.20	Second supplemental indenture dated as of June  24, 2014, between Petróleos Mexicanos and Deutsche Bank Trust Company Americas, to the indenture dated as of December 30, 2004 (previously filed as Exhibit 4.13 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-198588) on September 5, 2014 and incorporated by reference herein).

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2.21	Fourth supplemental indenture dated as of June  24, 2014, between Petróleos Mexicanos and Deutsche Bank Trust Company Americas, to the indenture dated as of January 27, 2009 (previously filed as Exhibit 4.14 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-198588) on September 5, 2014 and incorporated by reference herein).
2.22	Third supplemental indenture dated as of September  10, 2014, between Petróleos Mexicanos and Deutsche Bank Trust Company Americas, to the indenture dated as of July 31, 2000 (previously filed as Exhibit 2.22 to Petróleos Mexicanos’ annual report on Form 20-F (File No. 0-99) on April 30, 2015 and incorporated by reference herein).
2.23	Fifth supplemental indenture dated as of October  15, 2014, between Petróleos Mexicanos and Deutsche Bank Trust Company Americas, to the indenture dated as of January 27, 2009 previously filed as Exhibit 2.23 to Petróleos Mexicanos’ annual report on Form 20-F (File No. 0-99) on April 30, 2015 and incorporated by reference herein).
2.24	Sixth supplemental indenture dated as of December  8, 2015 between Petróleos Mexicanos and Deutsche Bank Trust Company Americas, to the indenture dated as of January 27, 2009 (previously filed as Exhibit 4.17 to Amendment No.  1 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-205763) on February 8, 2016 and incorporated by reference herein).
2.25	Seventh supplemental indenture dated as of June  14, 2016 between Petróleos Mexicanos and Deutsche Bank Trust Company Americas, to the indenture dated as of January 27, 2009 (previously filed as Exhibit 4.18 to Amendment No.  1 to the Petróleos Mexicanos Registration Statement on Form F-4 (File No. 333-213351) on August 26, 2016 and incorporated by reference herein).
2.26	Eighth supplemental indenture dated as of February 16, 2018 between Petróleos Mexicanos and Deutsche Bank Trust Company Americas, to the indenture dated as of January 27, 2009.

The registrant agrees to furnish to the U.S. Securities and Exchange Commission, upon request, copies of any instruments that define the rights of holders of long-term debt of the registrant that are not filed as exhibits to this report.

4.1	Receivables Purchase Agreement, dated as of December 1, 1998, by and among Pemex Finance, Ltd., P.M.I. Comercio Internacional, S.A. de C.V., P.M.I. Services, B.V. and Pemex-Exploración y Producción. (previously filed as Exhibit 3.3 to the Petróleos Mexicanos Annual Report on Form 20-F (File No. 0-99) on June 30, 1999 and incorporated by reference herein).(P)
7.1	Computation of Ratio of Earnings to Fixed Charges.
8.1	For a list of subsidiaries, their jurisdiction of incorporation and the names under which they do business, see “Consolidated Structure of PEMEX” on page 4.
10.1	Consent letters of Ryder Scott Company, L.P.
10.2	Reports on Reserves Data by Ryder Scott Company, L.P., Independent Qualified Reserves Evaluator or Auditor, as of December 31, 2017.
10.3	Consent letters of Netherland, Sewell International, S. de R.L. de C.V.
10.4	Reports on Reserves Data by Netherland, Sewell International, S. de R.L. de C.V., Independent Qualified Reserves Evaluator or Auditor, as of January 1, 2018.
10.5	Consent letters of DeGolyer and MacNaughton.
10.6	Reports on Reserves Data by DeGolyer and MacNaughton, Independent Qualified Reserves Evaluator or Auditor, as of January 1, 2018.
12.1	CEO Certification pursuant to Rule 13a-14(a)/15d-14(a).
12.2	CFO Certification pursuant to Rule 13a-14(a)/15d-14(a).
13.1	Certification pursuant to Rule 13a-14(b)/15d-14(b) and 18 U.S.C. §1350.

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101.INS	XBRL Instance Document.
101.SCH	XBRL Taxonomy Extension Schema Document.
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB	XBRL Taxonomy Extension Label Linkbase Document.
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document.

(P) Filed via paper.

240

SIGNATURE

Pursuant to the requirements of Section 12 of the Securities Exchange Act of 1934, as amended, the registrant hereby certifies that it meets all of the requirements for filing on Form 20-F and has duly caused and authorized the undersigned to sign this annual report on its behalf.

PETRÓLEOS MEXICANOS
By:	/s/ DAVID RUELAS RODRÍGUEZ
	Name:  David Ruelas Rodríguez Title:   Chief Financial Officer

Date: April 30, 2018

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

CONSOLIDATED FINANCIAL STATEMENTS

DECEMBER 31, 2017, 2016 AND 2015 AND REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

CONSOLIDATED FINANCIAL STATEMENTS

DECEMBER 31, 2017, 2016 AND 2015

Index

Contents	Page
Report of Independent Registered Public Accounting Firm	F-2
Consolidated statements:
Of financial position	F-4
Of comprehensive income	F-5
Of changes in equity (deficit), net	F-6
Of cash flows	F-7
Notes to the consolidated statements through	F-7 to F-151

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors of

Petróleos Mexicanos:

We have audited the accompanying consolidated statements of financial position of Petróleos Mexicanos, Productive State-Owned Subsidiaries and Subsidiary Companies (“PEMEX”) as of December 31, 2017 and 2016, and the related consolidated statements of comprehensive income, changes in equity (deficit), and cash flows for each of the three years in the period ended December 31, 2017. These consolidated financial statements are the responsibility of PEMEX’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. PEMEX is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of PEMEX’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the consolidated financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Petróleos Mexicanos, Productive State-Owned Subsidiaries and Subsidiary Companies as of December 31, 2017 and 2016, and the consolidated results of their operations and their cash flows for each of the three years in the period ended December 31, 2017, in conformity with International Financial Reporting Standards as issued by the International Accounting Standards Board.

The accompanying consolidated financial statements have been prepared assuming that PEMEX will continue as a going concern. As described in Note 2-b to the consolidated financial statements, PEMEX has suffered recurring losses from operations, has a working capital deficiency and a net equity deficit. As stated in Note 2-b, these events or conditions, along with other matters as set forth in such Note, indicate that a material uncertainty exists that may cast significant doubt on the PEMEX’s ability to continue as a going concern. Management’s plans in regard to these matters are also described in Note 2-b. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.

CASTILLO MIRANDA Y COMPAÑÍA, S. C.

/S/ JOSE LUIS VILLALOBOS ZUAZUA

C.P.C. Jose Luis Villalobos Zuazua

Mexico City,

April 30, 2018

F-2

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF FINANCIAL POSITION

AS OF DECEMBER 31, 2017 AND 2016

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

	Note		December 31, 2017			December 31, 2017			December 31, 2016
			(Unaudited; U.S. dollars)
ASSETS
Current assets:
Cash and cash equivalents		6	U.S. $	4,945,330		Ps.	97,851,754		Ps.	163,532,513
Accounts receivable, net		7		8,624,239			170,645,234			133,220,527
Inventories, net		8		3,227,366			63,858,930			45,892,060
Held-for-sale current non-financial assets		9		—			—			7,460,674
Available-for-sale financial assets		10-b.		53,416			1,056,918			2,852,679
Derivative financial instruments		16		1,521,904			30,113,454			4,857,470
Total current assets				18,372,255			363,526,290			357,815,923
Non-current assets:
Available-for-sale financial assets		10		—			—			6,027,540
Investments in joint ventures and associates		11		844,373			16,707,364			20,737,509
Wells, pipelines, properties, plant and equipment, net		12		72,599,743			1,436,509,326			1,667,742,248
Long-term notes receivable		14		7,504,683			148,492,909			148,607,602
Deferred taxes		20		7,388,422			146,192,485			100,324,689
Restricted cash		6		—			—			10,478,626
Intangible assets		13		459,327			9,088,563			8,639,242
Other assets		14		580,449			11,485,177			9,512,645
Total non-current assets				89,376,997			1,768,475,824			1,972,070,101
Total assets			U.S. $	107,749,252		Ps.	2,132,002,114		Ps.	2,329,886,024
LIABILITIES
Current liabilities:
Short-term debt and current portion of long-term debt		15	U.S. $	7,945,209		Ps.	157,209,467		Ps.	176,166,188
Suppliers				7,073,205			139,955,378			151,649,540
Taxes and duties payable		20		2,577,740			51,004,960			48,839,595
Accounts and accrued expenses payable				1,173,081			23,211,401			18,666,607
Derivative financial instruments		16		896,864			17,745,979			30,867,956
Total current liabilities				19,666,099			389,127,185			426,189,886
Long-term liabilities:
Long-term debt		15		95,046,956			1,880,665,604			1,807,004,542
Employee benefits		17		63,600,101			1,258,436,122			1,220,409,436
Provisions for sundry creditors		18		4,431,129			87,677,423			88,317,878
Other liabilities				717,363			14,194,237			16,837,893
Deferred taxes		20		214,988			4,253,928			4,134,536
Total long-term liabilities				164,010,537			3,245,227,314			3,136,704,285
Total liabilities			U.S. $	183,676,636		Ps.	3,634,354,499		Ps.	3,562,894,171
EQUITY (DEFICIT), NET		21
Controlling interest:
Certificates of Contribution “A”			U.S. $	18,019,399		Ps.	356,544,447		Ps.	356,544,447
Mexican Government contributions				2,210,100			43,730,591			43,730,591
Legal reserve				50,647			1,002,130			1,002,130
Accumulated other comprehensive result				(7,676,226	)		(151,887,182	)		(163,399,441	)
Accumulated deficit:
From prior years				(74,386,461	)		(1,471,862,579	)		(1,280,216,973	)
Net loss for the year				(14,193,620	)		(280,844,899	)		(191,645,606	)
Total controlling interest				(75,976,160	)		(1,503,317,492	)		(1,233,984,852	)
Total non-controlling interest				48,776			965,107			976,705
Total equity (deficit), net			U.S. $	(75,927,384	)	Ps.	(1,502,352,385	)	Ps.	(1,233,008,147	)
Total liabilities and equity (deficit), net			U.S. $	107,749,252		Ps.	2,132,002,114		Ps.	2,329,886,024

The accompanying notes are an integral part of these consolidated financial statements.

F-3

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(Figures stated in thousands, except as noted)

	Note		2017			2017			2016			2015
			(Unaudited; U.S. dollars)
Net sales:
Domestic		5	U.S. $	44,340,898		Ps.	877,360,038		Ps.	670,000,473		Ps.	746,235,912
Export		5		25,701,057			508,539,112			395,118,117			407,214,445
Services income		3-w,5		562,528			11,130,569			8,974,642			8,310,035
Total of sales				70,604,483			1,397,029,719			1,074,093,232			1,161,760,392
Impairment (reversal) of wells, pipelines, properties, plant and equipment, net		12-e		7,653,856			151,444,560			(331,314,343	)		477,944,690
Benefit from change in pension plan				—			—			—			(92,177,089	)
Cost of sales				50,751,509			1,004,204,880			865,822,221			891,964,606
Gross income (loss)				12,199,118			241,380,279			539,585,354			(115,971,815	)
Other revenues (expenses), net		22		261,493			5,174,076			22,649,606			(875,487	)
General expenses:
Distribution, transportation and sale expenses				1,106,282			21,889,670			25,231,240			28,928,639
Administrative expenses				6,061,620			119,939,454			112,653,533			112,472,095
Benefit from change in pension plan				—			—			—			(103,860,955	)
Operating income (loss)				5,292,708			104,725,231			424,350,187			(154,387,081	)
Financing income1				817,006			16,165,853			13,749,255			14,990,859
Financing cost2				(5,945,638	)		(117,644,548	)		(98,844,464	)		(67,773,593	)
Derivative financial instruments income (cost), net		16		1,280,574			25,338,324			(14,000,987	)		(21,449,877	)
Foreign exchange income (loss), net		16		1,171,702			23,184,122			(254,012,743	)		(154,765,574	)
				(2,676,356	)		(52,956,249	)		(353,108,939	)		(228,998,185	)
Profit sharing in joint ventures and associates		11		18,216			360,440			2,135,845			2,318,115
Income(loss) before duties, taxes and other				2,634,569			52,129,422			73,377,093			(381,067,151	)
Profit sharing duty, net		20		17,084,416			338,044,209			277,161,804			377,087,514
Income tax		20		(255,938	)		(5,064,168	)		(12,640,369	)		(45,587,267	)
Total duties, taxes and other				16,828,478			332,980,041			264,521,435			331,500,247
Net loss				(14,193,909	)		(280,850,619	)		(191,144,342	)		(712,567,398	)
Other comprehensive results:
Items that will be reclassified subsequently to profit or loss:
Available-for-sale financial assets		10		281,206			5,564,130			207,817			(3,206,316	)
Currency translation effect		19		(308,109	)		(6,096,459	)		21,386,903			13,262,101
Items that will not be reclassified subsequently to profit or loss:
Actuarial gains—employee benefits		17		608,424			12,038,710			106,277,761			78,556,569
Total other comprehensive results				581,521			11,506,381			127,872,481			88,612,354
Total comprehensive loss			U.S. $	(13,612,388	)	Ps.	(269,344,238	)	Ps.	(63,271,861	)	Ps.	(623,955,044	)
Net loss attributable to:
Controlling interest			U.S. $	(14,193,620	)	Ps.	(280,844,899	)	Ps.	(191,645,606	)	Ps.	(712,434,997	)
Non-controlling interest				(289	)		(5,720	)		501,264			(132,401	)
Net loss			U.S. $	(14,193,909	)	Ps.	(280,850,619	)	Ps.	(191,144,342	)	Ps.	(712,567,398	)
Other comprehensive results attributable to:
Controlling interest			U.S. $	581,818		Ps.	11,512,259		Ps.	127,650,318		Ps.	88,571,493
Non-controlling interest				(297	)		(5,878	)		222,163			40,861
Total other comprehensive results			U.S. $	581,521		Ps.	11,506,381		Ps.	127,872,481		Ps.	88,612,354
Comprehensive (loss) income:
Controlling interest			U.S. $	(13,611,802	)	Ps.	(269,332,640	)	Ps.	(63,995,288	)	Ps.	(623,863,504	)
Non-controlling interest				(586	)		(11,598	)		723,427			(91,540	)
Total comprehensive loss			U.S. $	(13,612,388	)	Ps.	(269,344,238	)	Ps.	(63,271,861	)	Ps.	(623,955,044	)

The accompanying notes are an integral part of these consolidated financial statements.

¹  Includes financing income from investments and gain on discount rate of plugging of wells in 2017, 2016 and 2015.

²  Mainly interest on debt.

F-4

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (DEFICIT), NET

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(Figures stated in thousands, except as noted)

(See Note 21)

	Controlling interest
							Accumulated other comprehensive income (loss)									Accumulated deficit
	Certificates of Contribution “A”		Mexican Government contributions		Legal reserve		Available- for sale financial assets			Cumulative currency translation effect			Actuarial (losses) gains on employee benefits effect			For the year			From prior years			Total			Non controlling interest			Total Equity (deficit), net
Balances as of January 1, 2015	Ps.	134,604,835	Ps.	43,730,591	Ps.	1,002,130	Ps.	(2,565,631	)	Ps.	16,320,433		Ps.	(408,349,268	)	Ps.	—		Ps.	(552,808,762	)	Ps.	(768,065,672	)	Ps.	344,818		Ps.	(767,720,854	)
Increase in Certificates of Contribution “A”		60,000,000		—		—		—			—			—			—			—			60,000,000			—			60,000,000
Total comprehensive (loss) income		—		—		—		(3,206,316	)		13,229,927			78,547,882			(712,434,997	)		—			(623,863,504	)		(91,540	)		(623,955,044	)
Balances as of January 1, 2016	Ps.	194,604,835	Ps.	43,730,591	Ps.	1,002,130	Ps.	(5,771,947	)	Ps.	29,550,360		Ps.	(329,801,386	)	Ps.	(712,434,997	)	Ps.	(552,808,762	)	Ps.	(1,331,929,176	)	Ps.	253,278		Ps.	(1,331,675,898	)
Transfer to accumulated deficit		—		—		—		—			—			—			712,434,997			(712,434,997	)		—			—			—
Increase in Certificates of Contribution “A”		161,939,612		—		—		—			—			—			—			—			161,939,612			—			161,939,612
Reclassification of other comprehensive income		—		—		—		—			—			14,973,214			—			(14,973,214	)		—			—			—
Total comprehensive (loss) income		—		—		—		207,817			21,169,662			106,272,839			(191,645,606	)		—			(63,995,288	)		723,427			(63,271,861	)
Balances as of December 31, 2016	Ps.	356,544,447	Ps.	43,730,591	Ps.	1,002,130	Ps.	(5,564,130	)	Ps.	50,720,022		Ps.	(208,555,333	)	Ps.	(191,645,606	)	Ps.	(1,280,216,973	)	Ps.	(1,233,984,852	)	Ps.	976,705		Ps.	(1,233,008,147	)
Transfer to accumulated deficit		—		—		—		—			—			—			191,645,606			(191,645,606	)		—			—			—
Total comprehensive income (loss)		—		—		—		5,564,130			(6,087,010	)		12,035,139			(280,844,899	)		—			(269,332,640	)		(11,598	)		(269,344,238	)
Balances as of December 31, 2017	Ps.	356,544,447	Ps.	43,730,591	Ps.	1,002,130	Ps.	—		Ps.	44,633,012		Ps.	(196,520,194	)	Ps.	(280,844,899	)	Ps.	(1,471,862,579	)	Ps.	(1,503,317,492	)	Ps.	965,107		Ps.	(1,502,352,385	)
Balances as of December 31, 2017 (Unaudited U.S. dollars)	U.S.$	18,019,399	U.S.$	2,210,100	U.S $	50,647	U.S.	—		U.S.$	2,255,708		U.S.$	(9,931,934	)	U.S.$	(14,193,620	)	U.S.$	(74,386,461	)	U.S.$	(75,976,160	)	U.S.$	48,776		U.S.$	(75,927,384	)

The accompanying notes are an integral part of these consolidated financial statements.

F-5

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(Figures stated in thousands, except as noted)

	2017			2017			2016			2015
	(Unaudited; U.S. dollars)
Operating activities
Net (loss)	U.S. $	(14,193,909	)		Ps. (280,850,619	)		Ps. (191,144,342	)		Ps. (712,567,398	)
Depreciation and amortization		7,919,689			156,704,513			150,439,491			167,951,250
(Reversal) impairment of wells, pipelines, properties, plant and equipment		7,653,856			151,444,560			(331,314,343	)		477,944,690
Unsuccessful wells		311,554			6,164,624			29,106,084			23,213,519
Exploration costs		(73,168	)		(1,447,761	)		(2,022,826	)		(5,698,511	)
Disposal of wells, pipelines, properties, plant and equipment		862,381			17,063,671			3,771,287			24,638,537
Loss in sale of fixed assets		—			—			27,882,480			—
Gain on sale of share in joint ventures and associates		(158,647	)		(3,139,103	)		(15,211,039	)		(680,630	)
Profit share in joint ventures and associates		(18,216	)		(360,440	)		(2,135,845	)		(2,318,115	)
Decrease on available—for-sale financial assets		68,743			1,360,205			—			—
Impairment of goodwill		—			—			4,007,018			—
Disposal of held—for—sale current non—financial assets		141,932			2,808,360			—			—
Dividends		(9,131	)		(180,675	)		(293,397	)		(359,941	)
Effects of net present value of reserve for well abandonment		392,890			7,774,000			11,968,966			(608,160	)
Net loss on available-for-sale financial assets		178,087			3,523,748			—			—
Unrealized foreign exchange (income) loss		(843,265	)		(16,685,439	)		243,182,764			152,676,256
Interest expense		5,945,638			117,644,548			98,844,464			67,773,593
		8,178,434			161,824,192			27,080,762			191,965,090
Derivative financial instruments		(1,939,584	)		(38,377,961	)		310,905			9,802,397
Accounts receivable		(1,370,831	)		(27,124,228	)		(55,104,439	)		33,003,083
Inventories		(908,028	)		(17,966,870	)		(1,358,879	)		6,167,728
Long-term receivables		5,796			114,693			(3,277,724	)		—
Intangible assets		(261,094	)		(5,166,184	)		(19,745,821	)		—
Other assets		(99,690	)		(1,972,532	)		(2,104,985	)		(16,602,365	)
Accounts payable and accrued expenses		229,689			4,544,794			3,097,660			1,002,403
Taxes and duties payable		19,144,463			378,805,745			311,015,217			384,109,597
Taxes and duties paid		(19,062,925	)		(377,192,377	)		(301,050,325	)		(351,370,004	)
Suppliers		(591,011	)		(11,694,162	)		(15,664,703	)		51,135,948
Provisions for sundry creditors		(339,351	)		(6,714,632	)		(11,413,361	)		(41,239,700	)
Employee benefits		2,530,255			50,065,396			47,293,069			(116,022,232	)
Deferred taxes		(2,312,079	)		(45,748,404	)		(43,802,181	)		(53,014,159	)
Net cash flows from (used in) operating activities		3,204,044			63,397,470			(41,898,083	)		98,937,786
Investing activities
Acquisition of wells, pipelines, properties, plant and equipment		(4,642,485	)		(91,859,465	)		(151,408,480	)		(253,514,001	)
Proceeds from available-for-sale financial assets		405,668			8,026,836			—			—
Proceeds from the sale of associates		158,779			3,141,710			22,684,736			4,417,138
Proceeds from the sale of fixed assets		—			—			560,665			—
Investments in associates		—			—			—			(36,214	)
Business acquisition		—			—			(4,329,769	)		—
Net cash flows used in investing activities		(4,078,038	)		(80,690,919	)		(132,492,848	)		(249,133,077	)
Financing activities
Increase in equity due to Certificates of Contributions “A”		—			—			73,500,000			10,000,000
Loans obtained from financial institutions		35,615,614			704,715,468			841,991,767			378,971,078
Debt payments, principal only		(32,342,434	)		(642,059,819	)		(614,987,329	)		(193,618,498	)
Interest paid		(5,504,223	)		(108,910,417	)		(88,754,141	)		(62,737,150	)
Net cash flows from financing activities		(2,231,043	)		(46,254,768	)		211,750,297			132,615,430
Net (decrease) increase in cash and cash equivalents		(3,211,663	)		(63,548,217	)		37,359,366			(17,579,861	)
Effects of foreign exchange on cash balances		(107,776	)		(2,132,542	)		16,804,267			8,960,213
Cash and cash equivalents at the beginning of the year		8,264,769			163,532,513			109,368,880			117,988,528
Cash and cash equivalents at the end of the year (Note 6)	U.S. $	4,945,330			Ps.  97,851,754			Ps.  163,532,513			Ps.  109,368,880

The accompanying notes are an integral part of these consolidated financial statements.

F-6

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

NOTE 1. STRUCTURE AND BUSINESS OPERATIONS OF PETRÓLEOS MEXICANOS, SUBSIDIARY ENTITIES AND SUBSIDIARY COMPANIES

Petróleos Mexicanos was created by a decree issued by the Mexican Congress on June 7, 1938. The decree was published in the Diario Oficial de la Federación (“Official Gazette of the Federation”) on July 20, 1938 and came into effect on that date.

On December 20, 2013, the Decreto por el que se reforman y adicionan diversas disposiciones de la Constitución Política de los Estados Unidos Mexicanos, en Materia de Energía (Decree that amends and supplements various provisions of the Mexican Constitution relating to energy matters), was published in the Official Gazette of the Federation and came into effect on December 21, 2013 (the “Energy Reform Decree”). In accordance with the Energy Reform Decree, the Mexican Government will carry out the exploration and extraction of hydrocarbons in the United Mexican States (“Mexico”) through assignments to productive state-owned companies, as well as through agreements with productive state-owned companies and with other companies.

As part of the secondary legislation enacted in accordance with the Energy Reform Decree, on August 11, 2014, the Ley de Petróleos Mexicanos (the “Petróleos Mexicanos Law”) was published in the Official Gazette of the Federation. The Petróleos Mexicanos Law became effective on October 7, 2014, except for certain provisions. On December 2, 2014, the Secretaría de Energía (“Ministry of Energy”) published in the Official Gazette of the Federation the declaration pursuant to which the special regime governing Petróleos Mexicanos’ activities relating to productive state-owned subsidiaries, affiliates, compensation, assets, administrative liabilities, state dividend, budget and debt levels came into effect. On June 10, 2015 the Disposiciones Generales de Contratación para Petróleos Mexicanos y sus Empresas Productivas Subsidiarias (General Contracting Provisions for Petróleos Mexicanos and its productive state-owned subsidiaries) was published in the Official Gazette of the Federation and thereafter the special regime for acquisitions, leases, services and public works matters came into effect.

Once the Petróleos Mexicanos Law came into effect, Petróleos Mexicanos was transformed from a decentralized public entity to a productive state-owned company. Petróleos Mexicanos is a legal entity empowered to own property and carry on business in its own name with the purpose of carrying out exploration and extraction of crude oil and other hydrocarbons in Mexico. In addition, Petróleos Mexicanos performs activities related to refining, gas processing and engineering and research projects to create economic value and to increase the income of the Mexican Government, as its owner, while adhering to principles of equity and social and environmental responsibility.

The Subsidiary Entities, Pemex Exploración y Producción (Pemex Exploration and Production), Pemex Transformación Industrial (Pemex Industrial Transformation), Pemex Perforación y Servicios (Pemex Drilling and Services), Pemex Logística (Pemex Logistics), Pemex Cogeneración y Servicios (Pemex Cogeneration and Services), Pemex Fertilizantes (Pemex Fertilizers) and Pemex Etileno (Pemex Ethylene), are productive state-owned subsidiaries empowered to own property and carry on business in their own name, subject to the direction and coordination of Petróleos Mexicanos (the “Subsidiary Entities”).

The Subsidiary Entities of Petróleos Mexicanos prior to the Corporate Reorganization (defined below) were Pemex-Exploración y Producción, Pemex-Refinación (Pemex-Refining), Pemex-Gas and Petroquímica Básica (Pemex-Gas and Basic Petrochemicals) and Pemex-Petroquímica (Pemex-Petrochemicals), which were

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

decentralized public entities with a technical, industrial and commercial nature with their own corporate identity and equity, with the legal authority to own property and conduct business in their own names, and were 100% owned by Petróleos Mexicanos and controlled by the Mexican Government; they had been consolidated into and had the characteristics of subsidiaries of Petróleos Mexicanos.

The Board of Directors of Petróleos Mexicanos, in its meeting held on November 18, 2014, approved the Corporate Reorganization proposed by the Chief Executive Officer of Petróleos Mexicanos.

Pursuant to the corporate reorganization, the existing four Subsidiary Entities were transformed into two new productive state-owned subsidiaries, which have assumed all of the rights and obligations of the existing Subsidiary Entities (the “Corporate Reorganization”). Pemex-Exploration and Production was transformed into Pemex Exploration and Production, a productive state-owned subsidiary, and Pemex-Refining, Pemex-Gas and Basic Petrochemicals and Pemex-Petrochemicals were transformed into the productive state-owned subsidiary Pemex Industrial Transformation.

The Board of Directors of Petróleos Mexicanos also approved the creation of the following new Subsidiary Entities: Pemex Drilling and Services, Pemex Logistics, Pemex Cogeneration and Services, Pemex Fertilizers and Pemex Ethylene. Each of these productive state-owned subsidiaries may be transformed into an affiliate of Petróleos Mexicanos if certain conditions set forth in the Petróleos Mexicanos Law are met.

On March 27, 2015, the Board of Directors of Petróleos Mexicanos approved the Estatuto Orgánico de Petróleos Mexicanos (Organic Statute of Petróleos Mexicanos) and the acuerdos de creación (creation resolutions) of each productive state-owned subsidiary. The Subsidiary Entities, and their primary purposes, are as follows:

• Pemex Exploration and Production: This entity is in charge of exploration and extraction of crude oil and solid, liquid or gaseous hydrocarbons in Mexico, in the exclusive economic zone of Mexico and abroad.

• Pemex Industrial Transformation: This entity performs activities related to refining, processing, importing, exporting, trading and the sale of hydrocarbons.

• Pemex Drilling and Services: This entity performs drilling services and repair and services of wells.

• Pemex Logistics: This entity provides transportation, storage and related services for crude oil, petroleum products and petrochemicals to PEMEX (as defined below) and other companies, through pipelines and maritime and terrestrial means, and provides guard and management services.

• Pemex Cogeneration and Services: This entity generates, supplies and trades electric and thermal energy, including but not limited to the energy and thermal power produced in power plants and cogeneration plants, as well as performing technical and management services related to these activities to PEMEX and other companies, by itself or through companies in which it participates directly or indirectly.

• Pemex Fertilizers: This entity produces, distributes and commercializes ammonia, fertilizers and its derivatives, as well as provides related services.

• Pemex Ethylene: This entity commercializes, distributes and trades methane, ethane and propylene, directly or through others.

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

On April 28, 2015 the creation resolutions of the seven productive state-owned subsidiaries were published in the Official Gazette of the Federation. Each creation resolution included a provision establishing that the creation resolution would come into effect once the required administrative procedures to start operations were in place and the Board of Directors of Petróleos Mexicanos issued and published a statement related to each creation resolution in the Official Gazette of the Federation.

On May 29, 2015 the statements related to the creation resolution of the productive state-owned subsidiary Pemex Exploration and Production and the productive state-owned subsidiary Pemex Cogeneration and Services issued by the Board of Directors of Petróleos Mexicanos were published in the Official Gazette of the Federation and, accordingly, these creation resolutions came into effect on June 1, 2015. On December 29, 2015 and May 12, 2016, modifications to the creation resolution of the productive state-owned subsidiary Pemex Exploration and Production were published in the Official Gazette of the Federation and became effective that same date, respectively.

On July 31, 2015, the statements related to the creation resolution of the productive state-owned subsidiary Pemex Drilling and Services, the productive state-owned subsidiary Pemex Fertilizers and the productive state-owned subsidiary Pemex Ethylene issued by the Board of Directors of Petróleos Mexicanos were published in the Official Gazette of the Federation and, accordingly, these creation resolutions came into effect on August 1, 2015.

On October 1, 2015, the statement related to the creation resolution of the productive state-owned subsidiary Pemex Logistics issued by the Board of Directors of Petróleos Mexicanos was published in the Official Gazette of the Federation and, accordingly, these creation resolutions came into effect on October 1, 2015.

On October 6, 2015, the statement related to the creation resolution of the productive state-owned subsidiary Pemex Industrial Transformation issued by the Board of Directors of Petróleos Mexicanos was published in the Official Gazette of the Federation and, accordingly, these creation resolutions came into effect on November 1, 2015.

As of the date of this report, all of the creation resolutions of the productive state-owned subsidiaries have come into effect.

The principal distinction between the Subsidiary Entities and the Subsidiary Companies (as defined below) is that the Subsidiary Entities are productive state-owned entities, whereas the Subsidiary Companies are affiliate companies that were formed in accordance with the applicable laws of each of the respective jurisdictions in which they were incorporated. The “Subsidiary Companies” are defined as those companies which are controlled, directly or indirectly, by Petróleos Mexicanos (see Note 3 a).

“Associates,” as used herein, means those companies in which Petróleos Mexicanos does not have effective control (see Note 3 a).

Petróleos Mexicanos, the Subsidiary Entities and the Subsidiary Companies are referred to collectively herein as “PEMEX.”

PEMEX’s address and its principal place of business is: Av. Marina Nacional No. 329, Col. Verónica Anzures, Delegación Miguel Hidalgo, 11300 Ciudad de México, México.

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

NOTE 2. BASIS OF PREPARATION

a. Statement of compliance

PEMEX prepared its consolidated financial statements as of December 31, 2017 and 2016, and for the years ended December 31, 2017, 2016 and 2015, in accordance with International Financial Reporting Standards (“IFRS”) as issued by the International Accounting Standards Board (“IASB”).

On April 27, 2018, these consolidated financial statements under IFRS and the notes hereto were authorized for issuance by the following officers: Mr. Carlos Alberto Treviño Medina, Chief Executive Officer, Mr. David Ruelas Rodríguez, Chief Financial Officer, Mr. Manuel Salvador Cruz Flores, Deputy Director of Accounting and Tax Matters, and Mr. Oscar René Orozco Piliado, Associate Managing Director of Accounting.

These consolidated financial statements and the notes hereto as of December 31, 2017 were approved by the Board of Petróleos Mexicanos on April 17, 2018 with prior approval from the Audit Committee of the report of the Independent Registered Public Accountant, pursuant to the terms of Article 13 Fraction VI of the Petróleos Mexicanos Law, Article 104 Fraction III, paragraph a, of the Ley del Mercado de Valores (Securities Market Law), and of Article 33 Fraction I, paragraph a, section 3 and Article 78 of the Disposiciones de carácter general aplicables a las emisoras de valores y a otros participantes del mercado de valores (General provisions applicable to securities´ issuers and other participants of the securities market).

b. Basis of measurement and going concern

These consolidated financial statements have been prepared using the historical cost basis method, except where it is indicated that certain items have been measured using the fair value model, amortized cost, present value or value in use. The principal items measured at fair value are derivative financial instruments (“DFIs”); the principal item measured at amortized cost is debt, the principal item measured at present value is the provision for employee benefits and some components of wells, pipelines, properties, plant and equipment are measured at value in use.

Going concern

The consolidated financial statements have been prepared on a going concern basis, which assumes that PEMEX can meet its payment obligations.

For the years ended December 31, 2017 and 2016, PEMEX recognized a net loss of Ps. 280,850,619 and Ps. 191,144,342, respectively, caused mainly by sustained low international oil prices, the high tax burden applicable to the industry, the depreciation of the peso relative to the U.S. dollar and an impairment of non-financial assets. In addition, as of December 31, 2017 and 2016, PEMEX had a negative equity of Ps. 1,502,352,385 and Ps. 1,233,008,147, respectively; a negative working capital of Ps. 25,600,895 and Ps. 68,373,963, respectively; and net cash flows used in operating activities of Ps. 41,898,083 for the year ended December 31, 2016. However, net cash flows from operating activities were Ps. 63,397,470, for the year ended December 31, 2017.

PEMEX believes net cash flows from its operating and financing activities, including its availability of lines of credit with certain banks, will be sufficient to meet its working capital needs, debt service and capital expenditure requirements and maintain its financial strength and flexibility in the twelve months following the date of issuance of these consolidated financial statements.

F-10

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

PEMEX continues to implement actions and business strategies that enable it to operate competitively and efficiently and take advantage of benefits of the Energy Reform Decree, as further described below:

• 2017-2021 Business Plan: On November 3, 2016, PEMEX announced its business plan for the five-year period from 2017 through 2021, which is designed to improve cash flows, reduce net indebtedness, strengthen its financial balance, reduce financial losses in its national refining system and plan for continued cost-cutting and administrative discipline, as well as the establishment of additional strategic alliances and partnerships, including an intensive farm-out program. The business plan was prepared conservatively and does not include additional income from the disposal of assets.

• Plan for 2017: The 2017 actions under the business plan established certain objectives with respect to its Subsidiary Entities that were implemented as follows:

• Pemex Exploration and Production’s investments focused on the most profitable projects, as well as on farm-outs and other partnerships aimed at increasing hydrocarbon production.

• On March 3, 2017, Pemex Exploration and Production signed the first farm-out project with BHP-Billiton for the Trion project and entered into a partnership with Chevron Energía de Mexico, S. de R.L. de C.V. (“Chevron”) and INPEX Corporation (“INPEX”) for the rights to block 3 North of the Cinturón Plegado Perdido in the Gulf of Mexico, both in deep waters.

• On May 2, 2017, Pemex Exploration and Production entered into an agreement with the Comisión Nacional de Hidrocarburos, (National Hydrocarbon Commission, or “NHC”) for crude oil drilling under the shared shallow-water production scheme for Ek-Balam field in the Campeche Basin.

• On May 30, 2017, Petróleos Mexicanos obtained approval from the NHC for the assignment of a new area that includes Chachiquin, located in the Cinturón Plegado Perdido region in the deep waters of the Gulf of Mexico south of the maritime border with the U.S., and an area southwest of the Nobilis field.

• Similarly, on June 19, 2017, Pemex Exploration and Production was awarded exploration and production fields bidding process (“Rounds”) in Round 2.1 the rights to develop two blocks in shallow waters: Block 2, in partnership DEA Deutsche Erdoel Ag (“DEA”) and Block B in partnership with Ecopetrol Global Energy, S.L.U. (“Ecopetrol”). On September 25, 2017, Pemex Exploration and Production signed the corresponding contracts for the exploration and extraction of hydrocarbons with DEA and Ecopetrol.

• On October 4, 2017, Pemex Exploration and Production finalized two farm-outs for the optimization of the development of the onshore fields of Cárdenas-Mora and Ogarrio, with Cheiron Holdings Limited (“Cheiron”) and DEA companies, respectively.

• On November 3, 2017, Petróleos Mexicanos announced the discovery of onshore light crude oil and gas reservoirs at the Ixachi-1 well in the state of Veracruz, Mexico, which PEMEX believes may contain over 1,500 million barrels of oil equivalent in place, representing 3P reserves of around 350 million barrels of oil equivalent. PEMEX believes that this discovery represents its largest onshore discovery in 15 years and that production can be accelerated due to the proximity of the reservoirs to existing infrastructure and to the Sistema Nacional de Gasoductos (National Gas Pipeline System.)

• On December 18, 2017, Pemex Exploration and Production and Petrofac México, S.A. de C.V., together with the NHC, signed the exploration and extraction contract for the onshore fields Santuario and El Golpe, which are located in the state of Tabasco.

F-11

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

• Pemex Industrial Transformation worked in partnerships for auxiliary services and the reconfiguration of certain refineries. On September 1, 2017, Pemex Industrial Transformation executed the auxiliary services contract with Air Liquide México. S.A. de R.L. de C.V. for ensuring and efficient hydrogen supply for the Miguel Hidalgo Refinery in Tula, Hidalgo.

• In September, 2017, Pemex Industrial Transformation began the selection process for partners for the hydrogen supply projects for the Héctor R. Lara Sosa Refinery in Cadereyta, Nuevo León and the Francisco I. Madero Refinery in Ciudad Madero, Tamaulipas. In April 2018, Pemex Industrial Transformation entered into a long-term agreement with the German company Linde AG for the supply of hydrogen to its Madero refinery.

• Pemex Logistics is being transformed from a company designed to ensure that Petróleos Mexicanos and its subsidiaries are properly supplied to one that provides profitable and competitive services to multiple customers. On May 2, 2017, PEMEX announced the results of the first Open Season Public Auction held by Pemex Logistics whereby, on July 18, 2017, PEMEX signed the contracts with Andeavor (formerly Tesoro Corporation). Under the contracts, Andeavor may use PEMEX’s pipeline transportation and storage system in the northwest of Mexico. On December 18, 2017, the Comisión Reguladora de Energía (the Energy Regulatory Commission, or “ERC”) approved Phase 2 of the Open Season.

• PEMEX’s business plan also describes its goal to increase the profitability of Pemex Fertilizers, Pemex Ethylene and Pemex Drilling and Services through service contracts and partnerships for the modernization of their facilities. On July 6, 2017, Pemex Ethylene, successfully concluded an e-auction to allocate quantities of ethylene oxide, in which 100% of the volume available was placed at a market price and was higher than the historical price.

• Plan for 2018: The 2018 actions under the business plan also set out certain objectives that PEMEX expects to achieve with respect to its Subsidiary Entities as follows:

• On January 31, 2018, PEMEX successfully participated in bidding Round 2.4, and was awarded the assignment of four blocks, all of which are located in deep waters in the Gulf of Mexico. Pemex Exploration and Production and Royal Dutch Shell PLC (“Shell”) were awarded Block 2 of the Perdido area. The consortium formed by Pemex Exploration and Production, Chevron and INPEX was awarded area 22 of the Cuenca Salina province. Finally, PEMEX was assigned on an individual basis, Block 5 in the Perdido area and area 18 of the Mexican Range province.

• On March 27, 2018, Petróleos Mexicanos successfully participated in bidding Round 3.1 of the NHC tenders, and was awarded seven contractual areas in shallow waters, six of them in a consortium and one on an individual basis. Pemex Exploration and Production won four blocks in the Southeast Basins: two in consortium with French Total S.A., one with Shell and one on an individual basis, as well as three blocks corresponding to the province of Tampico-Misantla-Veracruz: two in partnership with Compañía Española de Petróleos (“CEPSA”) and DEA and one more in partnership with CEPSA.

These contracts are intended to contribute to increase the reserves and hydrocarbon production with the respective economic benefits.

• Pemex Exploration and Production will focus on maintaining production levels and developing farm-outs and associations with the aim of increasing its operations and, with

F-12

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

time, the production of hydrocarbons in the mid-term. Pemex Exploration and Production will also accelerate the migration of integrated E&P contracts and financed public works contracts to Exploration and Extraction Contracts (“EEC”) and will focus on the rehabilitation and reincorporation activities of wells with production possibilities. In 2018, Pemex Exploration and Production will continue to promote actions that encourage efficiency and optimize costs.

• In order to continue to take advantage of the benefits of the Energy Reform and to ensure the economic sustainability of PEMEX, in 2018 and in the up-coming years, Pemex Exploration and Production will be focusing its efforts on the following strategies: (1) establishing a model of exploration that allows it to achieve the objective of incorporating and increasing proved reserves; (2) developing a master plan for the development of shales; (3) containing and reversing declines in the production of wells through reactivation and maintenance activities performed on closed wells through integrated services; (4) continuing with farm-outs to develop complex fields and leverage third-party resources; (5) establishing schemes, including strategic partnerships and alliances, to attract additional investment; (6) increasing revenues from hydrocarbons trading; and (7) strengthening operational efficiency and cost control.

• Pemex Industrial Transformation will continue to perform reconfiguration and auxiliary services for its refineries and to focus on the following strategies: (1) keeping its facilities safe and reliable, (2) improving the financial balance, (3) maintaining a market share in Mexico of over 65%; and (4) eliminating debts, which will help to improve its refining margin.

In addition to taking advantage of new business opportunities and arrangements provided by the Energy Reform, such as farm-outs, PEMEX also continues to take certain specific measures to improve its financial position, including the following:

• 2016 Budget Adjustment: In 2017, PEMEX developed actions from its Plan de Ajuste Presupuestal 2016 (“2016 Budget Adjustment Plan”) to reduce expenses which were included in its 2017-2021 Business Plan.

• Pension Reform. As of January 1, 2016, new employees are entitled to receive a defined contribution pension plan, pursuant to which both PEMEX and its employees contribute to each employee’s individual account, in contrast to the existing defined benefit pension plan, pursuant to which only PEMEX contributes. Additionally, in August 2017, PEMEX began the process of inviting existing employees to migrate from a defined benefit plan to a defined contribution plan, which will allow Pemex to decrease its employee benefits service cost and its employee benefits liability.

• Asset Sales. PEMEX continues to evaluate the divestiture of non-essential assets to obtain working capital and to focus on those activities considered as the most profitable. These projects include:

• On October 5, 2017, PEMEX announced the divestiture of its participation in the Ramones II Norte gas pipeline (50% interest of Pemex Industrial Transformation in Ductos y Energéticos del Norte, S. de R.L. de C.V., and 5% indirect interest of Pemex Industrial Transformation TAG Norte Holding, S. de R.L. de C.V.). On November 10, 2017, the Comisión Federal de Competencia Económica (the Federal Commission for Financial Competence) authorized the divestiture in Ductos y Energéticos del Norte, S. de R.L. de C.V., closing the operation on

F-13

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

November 16, 2017. PEMEX estimates that TAG Norte Holding, S. de R.L. de C.V. divestiture will conclude in the first semester of 2018.

• Decreased Debt Financing: PEMEX decreased its financing during 2017 from Ps. 231,618,067 of net indebtedness in 2016 to a net indebtedness of Ps. 72,412,672 in 2017. In addition, PEMEX developed liability management transactions in accordance with market conditions and in order to improve its financial profile, with longer due dates and better interest rates, as described in Note 15 to these consolidated financial statements. As a result of this strategy, Standard & Poor’s and Fitch increased PEMEX’s ratings outlook from negative to stable. For the fiscal year of 2018, the Federal Income Law applicable to PEMEX authorized for Petróleos Mexicanos and its Subsidiary Entities an internal net debt up to Ps. 30,000,000 and an external net debt up to U.S.$ 6,182,800. In addition, PEMEX will continue to assess opportunities for liability management in accordance with market conditions. In addition, as of December 31, 2017, PEMEX has five syndicated lines of credit to manage its liquidity for U.S.$6,700,000 and Ps.23,500,000.

• New Budget: On July 14, 2017, the Board of Directors of Petróleos Mexicanos approved a proposal for the annual consolidated budget of Petróleos Mexicanos and its Subsidiaries Entities for 2018, which was subsequently approved by the Chamber of Deputies on November 9, 2017.

The consolidated annual budget of Petróleos Mexicanos and its Subsidiary Entities for 2018 is approximately Ps. 391,946,000, a 1.7% increase as compared to the Ps. 385,211,257 consolidated annual adjusted budget for 2017.

• The structural changes arising from the Energy Reform, and the actions taken by management are aimed at ensuring the continuity of PEMEX’s operations, reducing costs, generating more revenue and operating more efficiently.

• In 2017, PEMEX entered into a crude oil hedge program to partially protect its cash flows from decreases in the price of Mexican crude oil.

Petróleos Mexicanos and its Subsidiary Entities are not subject to the Ley de Concursos Mercantiles (the Bankruptcy Law) and none of PEMEX’s existing financing agreements include any clause that could lead to the demand for immediate payment of the respective debt due to having negative equity.

PEMEX prepared its consolidated financial statements as of December 31, 2017 and 2016 on a going concern basis. There are certain conditions that have generated important uncertainty and significant doubts concerning the entity’s ability to continue operating, including recurring net losses, negative working capital and negative equity. These financial statements do not contain any adjustments that would be required if they were not prepared on a going concern basis.

c. Functional and reporting currency and translation of foreign currency operations

These consolidated financial statements are presented in Mexican pesos, which is both PEMEX’s functional and reporting currency, due to the following:

i. the economic environment in which PEMEX operates is Mexico, where the legal currency is the Mexican peso;

ii. Petróleos Mexicanos and its Subsidiary Entities have budgetary autonomy, subject only to maintaining the financial balance (the difference between income and total net spending, including the financial

F-14

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

cost of the public debt of the Mexican Government and the entities directly controlled by the Mexican Government) and the spending cap of personnel services proposed by SHCP and approved by the Mexican Congress, in Mexican pesos.

iii. Employee benefits provision was approximately 35% and 34% of PEMEX’s total liabilities as of December 31, 2017 and 2016, respectively. This provision is computed, denominated and payable in Mexican pesos; and

iv. cash flows for payment of general expenses, taxes and duties are realized in Mexican pesos.

Although the sales prices of several products are based on international U.S. dollar-indices, final domestic selling prices are governed by the economic and financial policies established by the Mexican Government. Accordingly, cash flows from domestic sales are generated and received in Mexican pesos.

Mexico’s monetary policy regulator, the Banco de México, requires that Mexican Government entities other than financial entities sell their foreign currency to the Banco de México in accordance with its terms, receiving Mexican pesos in exchange, which is the currency of legal tender in Mexico.

Translation of financial statements of foreign operations

The financial statements of foreign subsidiaries and associates are translated into the reporting currency by first identifying if the functional currency is different from the currency for recording the foreign operations, and, if so, the recording currency is translated into the functional currency and then into the reporting currency using the year-end exchange rate of each period for assets and liabilities reported in the consolidated statements of financial position; the historical exchange rate at the date of the transaction for equity items; and the weighted average exchange rate of the year for income and expenses reported in the statement of comprehensive income.

d. Terms definition

References in these consolidated financial statements and the related notes to “pesos” or “Ps.” refers to Mexican pesos, “U.S. dollars” or “US$” refers to dollars of the United States of America, “yen” or “¥” refers to Japanese yen, “euro” or “€” refers to the legal currency of the European Economic and Monetary Union, “Pounds sterling” or “£” refers to the legal currency of the United Kingdom, “Swiss francs” or “CHF” refers to the legal currency of the Swiss Confederation, “Canadian dollars” or “CAD” refers to the legal currency of Canada and “Australian dollars” or “AUD” refers to the legal currency of Australia. Figures in all currencies are presented in thousands of the relevant currency unit, except exchange rates and product and share prices.

e. Convenience translations

These consolidated financial statements are presented in Mexican pesos (reporting currency), which is the same as the recording currency and the functional currency of PEMEX. The U.S. dollar amounts shown in the consolidated statements of financial position, the consolidated statements of comprehensive income, the consolidated statements of changes in equity (deficit) and the consolidated statements of cash flows have been included solely for the convenience of the reader and are unaudited. Such amounts have been translated from amounts in pesos, as a matter of arithmetic computation only, at the exchange rate for the settlement of obligations in foreign currencies provided by Banco de México and SHCP at December 31, 2017 of Ps. 19.7867 per U.S. dollar. Translations herein should not be construed as a representation that the peso amounts have been or could be converted into U.S. dollars at the foregoing or any other rate.

F-15

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

NOTE 3. Significant accounting policies

The preparation of the consolidated financial statements in accordance with IFRS requires the use of estimates and assumptions made by PEMEX’s management that affect the recorded amounts of assets and liabilities and the disclosures of contingent assets and liabilities as of the date of these consolidated financial statements, as well as the recorded amounts of income, costs and expenses during the year.

Significant estimates and underlying assumptions are reviewed, and the effects of such revisions are recognized in the years in which any estimates are revised and in any future periods affected by such revision.

Information about estimates, assumptions and critical accounting policies that have the most significant effects on the amounts recognized in the consolidated financial statements are described in the following notes:

• Note 3(e) Financial instruments—determination of fair values

• Note 3(h) Wells, pipelines, properties, plant and equipment, including the successful efforts method—economic feasibility determining to capitalize assets

• Note 3(j) Impairment of non-financial assets—cash flow estimates and discount rates determination

• Note 3(l) Provisions—environmental liabilities and retirement of assets

• Note 3(m) Employee benefits—actuarial assumptions and hypothesis

• Note 3(n) Income taxes and duties—assessment of deferred income tax asset recovery

• Note 3(p) Contingencies—assessment of likelihood of contingency

Actual results could differ from those estimates and assumptions.

Below is a summary of the principal accounting policies, which have been consistently applied to each of the years presented and followed by PEMEX in the preparation of its consolidated financial statements:

a. Basis of consolidation

The consolidated financial statements include those of Petróleos Mexicanos, the Subsidiary Entities and the Subsidiary Companies. All intercompany balances and transactions of the consolidated companies; income and expenses, as well as unrealized profits and losses resulting from operations between them have been eliminated in the preparation of the consolidated financial statements pursuant to IFRS 10, “Consolidated Financial Statements” (“IFRS 10”).

Unrealized gains arising from transactions with entities whose investment is accounted for using the equity method are eliminated against the investment to the extent of PEMEX’s participation in such entities. Unrealized losses are eliminated in the same way as unrealized gains but only to the extent that there is no evidence of impairment of the investment. If such evidence exists, PEMEX recognizes it in its consolidated financial statements.

Investment in subsidiaries

The Subsidiary Entities and Subsidiary Companies are consolidated from the date that control commences until the date that control ceases.

F-16

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Petróleos Mexicanos controls a subsidiary when it is exposed to or has rights to variable returns from the company and has the ability to affect those returns through its power over the company.

The financial statements of the Subsidiary Entities and Subsidiary Companies have been prepared based on the same period of Petróleos Mexicanos’ consolidated financial statements applying the same accounting policies.

For more information about Subsidiary Companies, see Note 4.

Investments in associates and joint arrangements

Associates are those entities in which PEMEX has significant influence but not the power to control financial and operational decisions. It is presumed that there is significant influence when PEMEX owns directly or indirectly between 20% and 50% of voting rights in another entity.

Joint arrangements are those arrangements whereby two or more parties have joint control of an arrangement. A joint arrangement is either a joint venture, where both of the parties have rights to the net assets of the arrangements, or a joint operation, where the parties have both rights to the assets, and obligations for the liabilities relating to the arrangements.

Investments in associates and joint ventures are recognized based on the equity method and recorded initially at cost, including any goodwill identified on acquisition. With respect to joint operations, the assets, liabilities, income and expenses are recognized in relation to the share of each party and in accordance with the applicable IFRS for each of those items. The investment cost includes transaction costs.

These consolidated financial statements include the proportion of gains, losses and other comprehensive income corresponding to PEMEX’s share in each investee, once these items are adjusted to align with the accounting policies of PEMEX, from the date that significant influence and joint control begins to the date that such influence or joint control ceases.

When the value of the share of losses exceeds the value of PEMEX’s investment in an associate or joint venture, the carrying value of the investment, including any long-term investment, is reduced to zero and PEMEX ceases to recognize additional losses, except in cases where PEMEX is liable for obligations incurred by those associates and joint ventures.

For more information about associates and joint arrangements, see Note 11.

Non-controlling interests

The equity interests of third parties who do not have a controlling interest in the equity or comprehensive result of subsidiaries of PEMEX are presented in the consolidated statements of financial position, the consolidated statements of changes in equity (deficit) as “non-controlling interests” and as “net income and comprehensive income for the period, attributable to non-controlling interests,” in the consolidated statements of comprehensive income.

Changes in a parent’s ownership interest in a subsidiary that do not result in a loss of control are accounted for as equity transactions. In such circumstances, the carrying amounts of the controlling and non-controlling interests shall be adjusted to reflect the changes in their relative interests in the subsidiary.

F-17

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Dividends in cash and assets other than cash

A liability for distributions of dividends in cash and non-cash assets to third parties is recognized when the distribution is authorized by the Board of Directors. The corresponding amount is recognized directly in equity.

Distributions of dividends in non-cash assets are measured at the fair value of the assets to be distributed. Changes relating to these measurements of the fair value, between the date on which the distribution is declared and the date when the assets are transferred, are recognized directly in equity.

When distributing non-cash assets, any difference between the carrying amount of the liability for distribution of dividends and the carrying amount of the assets distributed is recognized in the consolidated statements of comprehensive income.

b. Business combinations and goodwill

Business combinations are accounted for using the acquisition method. The cost of an acquisition is measured as the aggregate of the consideration transferred, measured as the acquisition date fair value, and the amount of any non-controlling interest in the acquiree.

When PEMEX acquires a business, it assesses the acquired assets and liabilities in order to appropriately classify and designate each, taking into account the contractual terms, economic circumstances and other pertinent conditions as of the date of the acquisition. This includes the separation of embedded derivatives in host contractors by the acquiree. Acquired petroleum reserves and resources that can be reliably measured are recognized separately in the assessment of fair values on acquisition. Other potential reserves and rights, for which fair values cannot be reliably measured, are not recognized separately, but instead are subsumed in goodwill.

For business combinations achieved in stages, any previously held equity interest is measured at its acquisition date fair value, and any resulting gain or loss is recognized in income or loss or other comprehensive income.

Any contingent consideration to be transferred by the acquirer will be recognized at fair value on the acquisition date. Contingent consideration classified as an asset or liability that is a financial instrument and within the scope of IAS 39 “Financial instruments: Recognition and Measurement” is measured at fair value, with changes in fair value recognized in income or loss or other comprehensive income. If contingent consideration is not with the scope of IAS 39, it is measured in accordance with the appropriate IFRS requirement. Contingent consideration that is classified as equity is not remeasured, and subsequent settlement is accounted for within equity.

Goodwill, which is initially measured at cost, is the excess of the aggregate of the consideration transferred and the amount recognized for non-controlling interest over the fair value of the identifiable net assets acquired and liabilities assumed. If the fair value of the net asset acquired is greater than the aggregate consideration transferred (bargain purchase), before recognizing a gain, PEMEX reassesses whether it has correctly identified all of the assets acquired and all of the liabilities assumed and reviews the procedures used to measure the amounts to be recognized at the acquisition date. If the assessment still results in an excess of the fair value of net assets acquired over the aggregate consideration transferred, then the gain is recognized in the consolidated statements of comprehensive income.

F-18

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

After initial recognition, goodwill is measured at cost less any accumulated impairment losses. For the purpose of impairment testing, goodwill acquired in a business combination is, from the acquisition date, allocated to each cash generating unit that is expected to benefit from the combination, irrespective of whether other assets or liabilities of the acquiree are assigned to those units.

When goodwill is allocated to a cash generating unit and certain of the operations in that unit are disposed of, the goodwill associated with the disposed operation is included in the carrying amount of the operation when determining the gain or loss on disposal. Goodwill disposed in these circumstances is measured based on the relative values of the disposed operation and the portion of the cash generating unit retained.

c. Transactions in foreign currency

In accordance with IAS 21, “The Effects of Changes in Foreign Exchange Rates” (“IAS 21”), transactions in foreign currencies are translated and recorded at exchange rates at the dates of the transactions and/or of the presentation of financial information.

Exchange differences arising from the settlement of monetary items or from the translation of monetary items into rates different from those at which they were translated on their initial recognition, are recognized in the results of operations in the reporting period in which they arise. When a gain or loss from a non-monetary item is recognized in other comprehensive results, any exchange difference included in that gain or loss is recognized in other comprehensive results. Conversely, when a gain or loss from a non-monetary item is recognized in the results of operations, any exchange difference included in that gain or loss is recognized in the results of operations for the period.

d. Fair value measurement

PEMEX measures certain financial instruments such as DFIs at fair value as of the closing date of the relevant reporting period.

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. A measurement at fair value assumes that the sale of the asset or transfer of a liability occurs:

i. in the principal market for the asset or liability; or

ii. in the absence of a principal market, in the most advantageous market for the asset or liability.

The principal market or the most advantageous market must be accessible for PEMEX.

The fair value of an asset or liability is measured by using the same assumptions that market participants would make when pricing the asset or liability under the premise that market participants take into account highest and best use of the asset or liability.

e. Financial instruments

Financial instruments are classified as: (i) financial instruments measured at fair value through profit or loss; (ii) financial instruments held to maturity; (iii) available-for-sale financial assets; (iv) investments in equity instruments; (v) loans and receivables; and (vi) DFIs. PEMEX determines the classification of its financial instruments at the time of initial recognition.

F-19

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

PEMEX’s financial instruments include cash and short-term deposits, available-for-sale financial assets, accounts receivable, other receivables, loans, accounts payable to suppliers, other accounts payable, borrowings and debts, as well as DFIs.

Below are descriptions of the financial instruments policies employed by PEMEX:

Financial instruments measured at fair value through profit or loss

A financial instrument is measured at fair value through profit or loss if it is classified as held for trading or designated as such upon initial recognition. Financial assets are designated at fair value through profit or loss if PEMEX manages such investments and makes purchase and sale decisions based on their fair value in accordance with PEMEX’s documented risk management or investment strategy. In addition, directly attributable transaction costs are recognized in the consolidated statements of comprehensive income for the year. These financial instruments are recognized at fair value and corresponding changes relating to dividend income are recognized in the consolidated statements of comprehensive income.

Available-for-sale financial assets

Available-for-sale financial assets are non-DFIs that are designated as available-for-sale or are not classified in any of the previous categories. PEMEX’s investments in certain equity securities and debt securities are classified as available-for-sale financial assets. Available-for-sale financial assets are recognized initially at fair value plus any directly attributable transaction costs.

Subsequent to initial recognition, available-for-sale financial assets are measured at fair value. In addition, any gains or losses associated with such instruments, as well as foreign exchange differences are recognized in other comprehensive results and presented in the fair value reserve in equity. When an investment is derecognized, any gains or losses accumulated in the equity are reclassified to profit or loss.

Sales and purchases of financial assets that require the delivery of such assets within a period of time established by market practice are recognized as of the negotiation date (the date on which PEMEX commits to purchase or sell the asset).

Loans and receivables

Loans and receivables are initially recognized at fair value. After initial recognition, loans and debt securities that bear interest are measured at amortized cost using the effective interest rate (“EIR”) method, less impairment losses.

The amortized cost is calculated based on any discount or premium on acquisition and fees and costs that are an integral part of the EIR method. Amortization of costs is included under the heading of financing cost in the consolidated statements of comprehensive income.

Derivative financial instruments

DFIs presented in the consolidated statements of financial position are carried at fair value. In the case of DFIs held for trading, changes in fair value are recorded in profit or loss; in the case of DFIs formally designated

F-20

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

as and that qualify for hedging, changes in fair value are recorded in the consolidated statements of comprehensive income using cash flow or fair value hedge accounting, with gains or losses classified in accordance with the earnings treatment of the hedge transaction.

Embedded derivatives

PEMEX evaluates the potential existence of embedded derivatives, which may be found in the terms of its contracts, or combined with other host contracts, which could be structured financial instruments (debt or equity instruments with embedded derivatives). Embedded derivatives have terms that implicitly or explicitly meet the characteristics of a DFI. In some instances, these embedded derivatives must be segregated from the underlying contracts and measured, recognized, presented and disclosed as DFIs, such as when the economic risks and terms of the embedded derivative are not clearly and closely related to the underlying contract.

Impairment of financial assets

At each reporting date, PEMEX evaluates whether there is objective evidence that a financial asset or group of financial assets is impaired, in which case the value of the recoverable amount of the asset is calculated. A financial asset is impaired if objective evidence indicates that a loss event has occurred after the initial recognition of the asset, and that the loss event had a negative effect on the estimated future cash flows of the financial asset.

Objective evidence that a financial asset or group of assets is impaired includes significant financial difficulty of the issuer or obligor, a breach of contract, such as a default or delinquency in interest or principal payments; the lender, for economic or legal reasons relating to the borrower’s financial difficulty, granting to the borrower a concession that the lender would not otherwise consider; it becoming probable that the borrower will enter bankruptcy or other financial reorganization; the disappearance of an active market for that financial asset because of financial difficulties; or observable data indicating that there is a measurable decrease in the estimated future cash flows. Impairments by asset are:

Impairment of financial assets carried at amortized cost

The impairment of financial assets carried at amortized cost is measured as the difference between the assets carrying amount and the present value of estimated future cash flows (excluding future credit losses that have not been incurred) discounted at the financial asset’s original effective interest rate. The amount of the loss shall be recognized in profit or loss.

If, in a subsequent period, the amount of the impairment loss decreases and the decrease can be related objectively to an event occurring after the impairment was recognized, the impairment loss previously recognized shall be reversed in profit or loss.

Impairment in available—for—sale financial assets

In addition to the above-mentioned, a significant or prolonged decline in the fair value of an investment in an available—for—sale equity instrument is also objective evidence of impairment.

When there is objective evidence of the impairment of an asset, the accumulated loss recognized in other comprehensive income shall be reclassified from equity to profit or loss even though the financial asset has not been derecognized.

F-21

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

If, in a subsequent period, the impairment loss decreases, the reversal shall be reflected as a reversal in other comprehensive income.

f. Cash and cash equivalents

Cash and cash equivalents are comprised of cash balances on hand, net of overdrafts, deposits in bank accounts, foreign currency reserves and instruments with maturities of three months or less from the acquisition date that are subject to an insignificant risk of changes in their fair value, which are used in the management of PEMEX’s short-term commitments.

Cash subject to restrictions or that cannot be exchanged or used to settle a liability within 12 months is presented as non-current assets.

g. Inventories and cost of sales

Inventories are valued at the lower of cost or net realizable value. Cost is determined based on the cost of production or acquisition of inventory and other costs incurred in transporting such inventory to its present location and in its present condition, using the average cost formula. Net realizable value is the estimated selling price in the ordinary course of business less the estimated costs of completion and the estimated selling costs. The estimate takes into consideration, among other things, the decrease in the value of inventories due to obsolescence.

Cost of sales represents the cost of production or acquisition of inventories at the time of sale, increased, where appropriate, by declines in net realizable value of inventories during the year.

Advance payment to suppliers for inventory purchases are recognized as part of inventory when the risks and benefits of the ownership of the inventory have been transferred to PEMEX.

h. Wells, pipelines, properties, plant and equipment

Wells, pipelines, properties, plant and equipment are recorded at acquisition or construction cost less accumulated depreciation and accumulated impairment losses.

PEMEX uses the successful efforts method for the exploration and production of crude oil and gas activities, considering the criteria mentioned in IFRS 6, “Exploration for and Evaluation of Mineral Resources” in relation to the recognition of exploration and drilling assets. Costs of development wells and related plant, property and equipment involved in the exploitation of oil and gas are recorded as part of the cost of assets. The costs of exploratory wells in areas that have not yet been designated as containing proved reserves are recorded as intangible assets until it is determined whether they are commercially viable to capitalize as fixed assets, otherwise they are recognized as exploration expenses. Other expenditures on exploration are recognized as exploration expenses as they are incurred.

In accordance with IAS 16, “Property, Plant and Equipment” (“IAS 16”), initial costs of wells, pipelines, properties, plant and equipment are initially recorded at cost, which includes their original purchase price or construction cost, any costs attributable to bringing the assets to a working condition for their intended use and the costs of dismantling and removing the items and restoring the site on which they are located, including the estimated cost of plugging and abandoning wells.

F-22

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The cost of financing projects that require large investments and financing incurred for projects, net of interest revenues from the temporary investment of these funds, is recognized as part of wells, pipelines, properties, plant and equipment when the cost is directly attributable to the construction or acquisition of a qualifying asset. The capitalization of these costs is suspended during periods in which the development of construction is interrupted, and its capitalization ends when the activities necessary for the use of the qualifying asset are substantially completed. All other financing costs are recognized in the consolidated statements of comprehensive income in the period in which they are incurred.

The cost of self-constructed assets includes the cost of materials and direct labor, interest on financing and any other costs directly attributable to start up. In some cases the cost also includes the cost of plugging of wells and removal.

Expenditures related to the construction of wells, pipelines, properties, plant and equipment during the stage prior to commissioning are stated at cost as intangible assets or construction in progress, in accordance with the characteristics of the asset. Once the assets are ready for use, they are transferred to the respective component of wells, pipelines, properties, plant and equipment and depreciation or amortization begins.

The costs of major maintenance or replacement of a significant component of an item of wells, pipelines, properties, plant and equipment are recognized in the carrying amount of the item if it is probable that the future economic benefits embodied within the component will flow to PEMEX and its cost can be measured reliably. The costs of recurring maintenance, repairs and renovations of wells, pipelines, properties, plant and equipment carried out to maintain the facilities in normal operation conditions are recognized in profit or loss as incurred.

Depreciation and amortization of capitalized costs in wells are determined based on the estimated economic life of the field to which the wells belong, considering the relationship between the production of barrels of oil equivalent for the period and proved developed reserves of the field, as of the beginning of the period, with quarterly updates for new development investments.

Depreciation of other elements of pipelines, properties, plant and equipment is recognized in profit or loss on a straight-line basis over the estimated useful life of the asset, beginning as of the date that the asset is available for use, or in the case of construction, from the date that the asset is completed and ready for use.

When parts of an item of wells, pipelines, properties and equipment are significant relative to the total cost of the item, the part is depreciated separately.

Estimated useful lives of items of properties, plant and equipment are reviewed if expectations differ from previous estimates.

Pipelines, properties, and equipment received from customers are initially recognized at fair value as revenue from ordinary operating activities if PEMEX has no future obligations to the customer who transferred the item. In contrast, if PEMEX does have future obligations to such a customer, the initial recognition is recorded as a deferred liability based on the period in which the assets will provide services to the customers.

The capitalized value of finance leases is also included in the line item of wells, pipelines, properties, plant and equipment. Properties, plant and equipment acquired through financial leases are depreciated over the shorter of the lease term or the useful life of the asset.

F-23

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Advance payments for the acquisition of pipelines, properties, plant and equipment are also recognized in the line item of wells, pipelines, properties, plant and equipment when the risks and benefits of the ownership have been transferred to PEMEX.

i. Crude oil and natural gas reserves

Under Mexican law, all crude oil and other hydrocarbon reserves located in the subsoil of Mexico are owned by the Mexican nation and not by PEMEX. In accordance with the aforementioned and based on the applicable regulation as of the date of these consolidated financial statements, the reserves assigned to PEMEX by the Mexican Government are not registered for accounting purposes because they are not PEMEX’s property. PEMEX estimates total proved oil and natural gas reserve volumes in accordance with the definitions, methods and procedures established in Rule 4-10(a) of Regulation S-X (“Rule 4-10(a)”) of the U.S. Securities and Exchange Commission (“SEC”) as amended, and where necessary, in accordance with the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers (the “SPE”) as of February 19, 2007. These procedures are consistent with international reserves reporting practice. The estimation of these reserves depends on assumptions made and the interpretation of the data available, and may vary among analysts. The results of drilling activities, test wells and production after the date of estimation are utilized in future revisions of reserves estimates.

Although PEMEX does not own the oil and other hydrocarbon reserves within Mexico, these procedures allow PEMEX to record the effects that such oil and other hydrocarbon reserves have on its consolidated financial statements, including, for example, in the depreciation and amortization line item.

j. Impairment of non-financial assets

The carrying amounts of PEMEX’s non-financial assets, other than inventories and deferred taxes, are assessed for indicators of impairment at the end of each reporting period. If the net carrying value of the asset or its cash-generating unit exceeds the recoverable amount, PEMEX records an impairment charge in its consolidated statement of comprehensive income.

A cash-generating unit is the smallest identifiable group of assets which can generate cash flows independently from other assets or groups of assets.

The recoverable amount of an asset or a cash-generating unit is defined as the higher of its fair value minus the costs of disposal and its value in use. The value in use is the discounted present value of the net future cash flows expected to arise from the continuing use of an asset and from its disposal at the end of its useful life. In measuring value in use, the discount rate applied is the pre-tax rate that reflects current market assessments of the time value of money and the risks specific to the asset. Fair value is calculated using discounted cash flows determined by the assumptions that market participants would apply in order to estimate the price of an asset or cash generating unit, assuming that such participants were acting in their best economic interest.

In the case of cash-generating assets or items dedicated to the exploration and evaluation of hydrocarbons reserves, the recoverable amount is determined using the value in use based on the proved reserves and probable reserves, in some cases, for the risk factor associated with such reserves.

Both impairment losses and reversals are recognized in the statement of comprehensive income in the costs and expenses line items in which the depreciation and amortization are recognized. Impairment losses may not be

F-24

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

presented as part of the costs that have been capitalized in the value of any asset. Impairment losses related to inventories are recognized as part of cost of sales. Impairment losses on investments in associates, joint ventures and other investments are recognized as profit (loss) sharing in associates.

An impairment loss shall be reversed if there has been a change in the estimates used since the date when the impairment loss was recognized. These reversals will not exceed the carrying value of the asset as though no impairment had been recognized. Impairment losses and reversals are presented in a separate line item in the statement of comprehensive income.

k. Leases

The determination of whether an agreement is or contains a lease is based on the economic substance of the agreement at the date of execution. An agreement contains a lease if performance under the agreement depends upon the use of a specific asset or assets, or if the agreement grants the right to use the asset.

Finance leases, which transfer to PEMEX substantially all the inherent benefits and risks of the leased property, are capitalized at the date the lease commences, and the value is recorded as the lower of the fair value of the leased property and the present value of the minimum lease payments. Payments on the lease are divided between the financial costs and the amortization of the remaining debt principal in order to achieve a constant effective interest rate for the outstanding liability. The financing costs are recognized in the statement of comprehensive income.

Operating lease payments are recognized as expenses in the statement of comprehensive income on a straight line basis over the term of the lease and variable rent payments are recognized in the operating results on an accrued basis.

l. Provisions

PEMEX recognizes provisions when, as a result of a past event, PEMEX has incurred a legal or assumed present obligation for which a future disbursement is probable and the value of such disbursement is reasonably estimable. In certain cases, such amounts are recorded at their present value.

Environmental liabilities

In accordance with applicable legal requirements and accounting practices, an environmental liability is recognized when the cash outflows are probable and the amount is reasonably estimable. Disbursements related to the conservation of the environment that are linked to revenue from current or future operations are accounted as expenses or assets, depending on the circumstances of each disbursement. Disbursements related to past operations, which no longer contribute to current or future revenues, are accounted for as current period expenses.

The accrual of a liability for a future disbursement occurs when an obligation related to environmental remediation, for which PEMEX has the information necessary to determine a reasonable estimated cost, is identified.

F-25

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Retirement of assets

The obligations associated with the future retirement of assets, including those related to the retirement of wells, pipelines, properties, plant and equipment and their components are recognized at the date that the retirement obligation is incurred, based on the discounted cash flow method. The determination of the fair value is based on existing technology and regulations. If a reliable estimation of fair value cannot be made at the time the obligation is incurred, the accrual will be recognized when there is sufficient information to estimate the fair value.

The obligations related to the costs of future retirement of assets associated with the principal refining processes for gas and petrochemicals are not recognized. These assets are considered to have an indefinite useful life due to the potential for maintenance and repairs.

The abandonment costs related to wells currently in production and wells temporarily closed are recorded in the statement of comprehensive income based on the units of production method. Total cost of abandonment and plugging for non-producing wells is recognized in the statement of comprehensive income at the end of each period. All estimations are based on the useful lives of the wells, considering their discounted present value. Salvage values are not considered, as these values commonly have not traditionally existed.

m. Employee benefits

Beginning January 1, 2016, Petróleos Mexicanos and the Subsidiary Entities have operated both a defined contribution plan and a defined benefit pension plan. Until December 31, 2015, PEMEX only operated a defined benefit pension plan.

Defined contribution pension plan

In this plan, both Petróleos Mexicanos and the Subsidiary Entities and their respective employees contribute to the worker’s individual account. PEMEX’s contributions are recognized on an accrual basis as cost, expense or asset, and are credited to liability.

Contributions to the defined contribution plan that are not expected to be fully settled within 12 months after the end of the annual reporting period in which the employee rendered related services will be discounted using the defined benefit plan discount rate.

Defined benefit plan

Under the defined benefit plan, Petróleos Mexicanos and the Subsidiary Entities are the only parties that contribute to a trust, which is managed separately. Petróleos Mexicanos and the Subsidiary Entities recognize the cost for defined benefit plans based on independent actuarial computations applying the projected unit credit method. Actuarial gains and losses are recognized within other comprehensive results for the period in which they are determined.

The costs of prior services are recognized within profit or loss for the period in which they are determined.

The asset or liability in the defined benefit plan comprises the present value of the defined benefit obligation less the fair value of plan assets for which obligations have to be settled. The value of any asset is limited to the present value of any economic benefit represented by the plan reimbursements or reductions of the future contributions to the plan.

F-26

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

In addition, other long term employee benefits include the seniority premiums payable for disability, death and survivors benefits, medical services, gas and basic food basket for beneficiaries.

Termination benefits are recognized in profit or loss for the year in which they are incurred.

n. Income taxes and duties

Current income tax

Current income tax assets or liabilities for the current and prior years are measured as the amount expected to be paid or to be recovered from the tax authorities, using either the tax rates in force or tax rates which are in the process of being approved and are substantially completed by the end of the year.

Current income taxes related with items that are recognized as equity are presented in the other comprehensive income of the year. Periodically, PEMEX evaluates the positions taken in its tax returns for those regulations that are subject to interpretation and books corresponding provisions, if it is deemed necessary.

Deferred income taxes

Deferred taxes are recorded based on the assets and liabilities method, which consists of the recognition of deferred taxes by applying tax rates applicable to the income tax to the temporary differences between the carrying value and tax values of assets and liabilities at the date of these consolidated financial statements.

Deferred tax liabilities are recognized for all taxable temporary differences, except to the extent that the deferred tax liability arises from:

• the initial recognition of goodwill or the initial recognition of an asset or liability in a transaction which is not a business combination and at the time of the transaction, affects neither accounting profit nor taxable profit or tax loss; and

• taxable temporary differences associated with investments in subsidiaries, branches and associates, and interest in joint arrangements, when the parent, investor, joint venture or joint operator is able to control the timing of reversal of the temporary difference and it is probable that the temporary difference will not reverse in the foreseeable future.

Deferred tax assets are recognized for all deductible temporary differences and the carry forward of both unused tax credits and unused tax losses to the extent that it is probable that taxable profit will be available against deductible temporary differences, and that the carry forward of both unused tax credits and unused tax losses can be utilized, unless:

• the deferred tax asset relating to deductible temporary difference arises from the initial recognition of asset or liability derived from a transaction that is not a business combination and, at the time of the transaction, affects neither accounting profit nor taxable profit or tax loss; and

• in respect of deductible temporary differences associated with investments in subsidiaries, associates and interests in joint ventures, deferred tax assets are recognized only to the extent that it is probable that the temporary differences will reverse in the foreseeable future and taxable profit will be available, against which the temporary differences can be utilized.

F-27

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The carrying amount of a deferred tax asset is reviewed at the end of each reporting period. PEMEX reduces the carrying amount of a deferred tax asset to the extent that it is no longer probable that a sufficient taxable profit will be available to allow the benefit of that deferred tax asset to be utilized in whole or in part. Unrecognized deferred tax assets are revalued at each reporting date and will be recognized to the extent that it is probable that future taxable income will be sufficient to allow for the recovery of the deferred tax asset.

Deferred tax assets and liabilities are measured at the tax rates that are expected to apply to the period when the asset is realized or the liability is settled, based on tax rates (and tax laws) that have been enacted or substantively enacted by the end of the reporting period.

Deferred tax assets and deferred tax liabilities related with items that are recognized in equity shall be presented directly in other comprehensive income.

Deferred tax assets and deferred tax liabilities are offset if PEMEX has a legal right to set off current tax assets against current tax liabilities and are levied by the same taxation authority or the same taxable entity.

Income taxes and duties

PEMEX is subject to taxes and special duties, which are based on the value of hydrocarbons extracted, with certain deductions.

These taxes and duties are recognized in accordance with IAS 12, “Income Taxes” (IAS 12), when they have the characteristics of income tax, which occurs when such taxes are set by a government authority and are determined on a formula that considers the balance of income (or extraction valued at a selling price) less expenses. Taxes and duties that meet this criteria should be recognized for current and deferred income tax based on the above paragraphs. Taxes and duties that do not meet this criteria are recognized as liabilities, affecting the costs and expenses relating to the transactions that gave rise to them.

o. Impuesto Especial sobre Producción y Servicios

(Special Tax on Production and Services, or “IEPS Tax”)

The IEPS Tax charged to customers is a withholding tax on domestic sales of gasoline, diesel and fossil fuels. The applicable quotas depend on, among other factors, the product, producer’s price, freight costs, commissions and the region in which the respective product is sold. The withholding tax does not affect the results of PEMEX.

p. Contingencies

Contingency losses are recorded when it is probable that a liability has been incurred and the amount thereof can be reasonably estimated. When a reasonable estimation cannot be made, qualitative disclosure is provided in the notes to the consolidated financial statements. Contingent revenues, earnings or assets are not recognized until realization is assured.

F-28

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

q. Revenue recognition

Sales revenue is recognized at the moment when the risks and benefits of ownership of crude oil, refined or gas products, and derivative and petrochemical products are transferred to the customers who acquire them, which occurs as follows:

• in accordance with contractual terms;

• the moment at which the customer picks up product at PEMEX’s facilities; or

• the moment at which PEMEX delivers the product to the delivery point.

Services rendered are recognized as services income when the customers accept the receipt of the services.

r. Presentation of consolidated statements of comprehensive income

The costs and expenses shown in PEMEX’s consolidated statements of comprehensive income are presented based on their function, which allows for a better understanding of the components of PEMEX’s operating income. This classification allows for a comparison to the industry to which PEMEX belongs.

Revenues

Represents revenues from sale or products or services.

Cost of sales

Cost of sales represents the acquisition and production costs of inventories at the time of sale. Cost of sales mainly includes depreciation, amortization, salaries, wages and benefits, a portion of the cost of the reserve for employee benefits and operating expenses related to the production process.

Other revenues (expenses), net

Other revenues (expenses), net consist primarily of income and expenses that are not related directly to the operation of PEMEX.

Transportation, distribution and sale expenses

Transportation, distribution and sale expenses are costs in connection with the storage, sale and delivery of products, such as the depreciation and operating expenses associated with these activities.

Administrative expenses

Administrative expenses are costs related to PEMEX’s areas that provide administrative support.

Financing income

Financing income is comprised of interest income, financial income and other income from financial operations between PEMEX and third parties.

F-29

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Financing cost

Financing cost is comprised of interest expenses, commissions and other expenses related to PEMEX’s financing operations less any portion of the financing cost that is capitalized.

Derivative financial instruments (cost) income, net

Derivative financial instruments (cost) income represents the net effect of the profit or loss for the year associated with DFIs.

Foreign exchange loss, net

Exchange rate variations relating to assets or liabilities governed by contracts denominated in foreign currencies are recorded in income (loss) for the year.

s. Operating segments

Operating segments are identifiable components of PEMEX that pursue business activities from which PEMEX earns revenues and incurs expenses, including those revenues and expenses from transactions with other segments of PEMEX, and for which information is available to management on a segmented basis and is assessed by the Board of Directors in order to allocate resources and assess the profitability of the segments.

t. Non-current assets held for sale, non-current assets held for distribution to owners and discontinued operations

Non-current assets held for sale

PEMEX classifies a non-current asset, or a disposal group of assets, as held for sale if (a) its carrying amount will be recovered principally through a sale transaction rather than through continuing use; (b) the asset or group of assets is available in its present condition for immediate sale and (c) the sale is expected to be completed within one year from the date of classification, or more, with certain exceptions.

Non-current assets classified as held for sale are measured at the lower of its carrying amount, and fair value less cost of sales and presented in a separate line item in the consolidated statements of financial position. Non-current assets classified as held for sale are not subject to depreciation or amortization after the classification as held for sale.

The liabilities of a disposal group classified as held for sale are presented separately from other liabilities in the statement of financial position. Those assets and liabilities are not offset and are presented as a single amount.

Non-current asset held for distribution to owners

When PEMEX agrees to distribute a non-current asset, or a disposal group of assets, to owners, this asset or disposal group of assets, is classified as held for distribution to owners if: a) a non-current asset or disposal group of assets is available for immediate distribution in its present condition and b) the distribution must be highly expected to be completed within one year from the date of classification, with certain exceptions.

F-30

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Non-current assets classified as held for distribution are measured at the lower of their carrying amount and fair value less cost of distribution and are presented in a separate line item in the consolidated financial statements. Non-current assets classified as held for distribution are not subject to depreciation or amortization after the classification as held for distribution.

The liabilities of a disposal group classified as held for distribution to owners are presented separately from other liabilities in the statement of financial position. Those assets and liabilities shall not be offset and shall be presented as a single amount.

Discontinued operations

A discontinued operation is a component of an entity that either has been disposed of or is classified as held for sale, and either:

• represents a separate major line of business or geographical area of operations;

• is part or a single coordinated plan to dispose of a separated major line of business or geographical area of operations; or

• is a subsidiary acquired exclusively with a view to resale.

The revenues or expenses from discontinued operations, including profits or losses from previous years, are presented in a specific line item in the consolidated statements of comprehensive income.

u. Accounting changes

The IASB issued new amendments to the IFRS mentioned below, which are applicable to PEMEX and are effective for annual periods beginning January 1, 2017:

a) IAS 12 “Income Taxes: Recognition of Deferred Tax Assets for Unrealized Losses” (“IAS 12”)

The IASB issues amendments to IAS 12 to clarify the diversity of practices in the recognition of deferred tax assets for unrealized losses related to debt instruments measured at fair value.

The amendments to IAS 12 include some explanatory paragraphs and an illustrative example.

The amendments clarify the following aspects of IAS 12:

• Unrealized losses on debt instruments measured at fair value for accounting purposes and measured at cost for tax purposes give rise to deductible temporary differences regardless of whether the debt instrument’s holder expects to recover the carrying amount of the debt instrument by sale or by use.

• The carrying amount of an asset does not limit the estimation of probable future taxable profits.

• Estimates of future taxable profits exclude tax deductions resulting from the reversal of deductible temporary differences.

• An entity assesses a deferred tax asset in combination with other deferred tax assets. Where tax law restricts the utilization of tax losses, an entity would assess a deferred tax asset in combination with other deferred tax assets of the same type.

F-31

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The amendments are to be applied retrospectively and are effective for annual periods beginning on or after January 1, 2017. Earlier application is permitted.

These amendments had no impact on these consolidated financial statements.

b) Amendments to IAS 7 “Statement of Cash Flows” (“IAS 7”)

The IASB issued amendments to IAS 7. The amendments are intended to clarify disclosure provided to the user of financial statements about an entity’s financing activities.

Changes

The amendments in IAS 7 come with the objective that entities shall provide disclosures that enable users of financial statements to evaluate changes in liabilities arising from financing activities.

To achieve this objective, the IASB requires that the following changes in liabilities arising from financing activities are disclosed: (i) changes from financing cash flows; (ii) changes arising from obtaining or losing control of subsidiaries or other businesses; (iii) the effects of changes in foreign exchange rate; (iv) changes in fair values; and (v) other changes.

The IASB defines liabilities arising from financing activities as liabilities “for which cash flows were, or future cash flows will be, classified in the statements of cash flows as cash flows from financing activities.” It also stresses that the new disclosure requirements also relate to changes in financial assets if they meet the same definition.

The amendments state that one way to fulfill the new disclosure requirements is to provide reconciliation between the opening and closing balances in the statement of financial position for liabilities arising from financing activities.

Finally, the amendments state that changes in liabilities arising from financing activities must be disclosed separately from changes in other assets and liabilities.

The amendments are effective for annual periods beginning on or after January 1, 2017. Earlier application is permitted. Entities need not provide comparative information when they first apply the amendments.

Impacts on this amendments are disclosed in Note 15.

c) IFRS 12 “Disclosure of Interest in Other Entities” (“IFRS 12”)—Annual Improvements to IFRS 2014—2016 Cycle.

As of December 2016, the IASB published Annual Improvements to IFRS 2014—2016 Cycle, which clarified the scope of IFRS 12, by specifying that the disclosure requirements apply to all subsidiaries, joint arrangements, associates and unconsolidated structured entities classified as held for sale, held for distribution or as discontinued operations in accordance with IFRS 5, with certain exceptions.

F-32

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The amendments are going to be applied restrospectively and are effective for annual periods beginning on or after January 1, 2017.

These improvements had no impact on these consolidated financial statements.

v. New IFRS not yet adopted

The IASB issued amendments and new IFRS that are not effective as of December 31, 2017 but that could have an impact on subsequent PEMEX financial statements.

Amendments effective for periods beginning in 2018:

a) IFRS 15, “Revenue from Contracts with Customers” (“IFRS 15”)

The core principle of the new IFRS 15 is that an entity should recognize revenue as the promised transfer of goods or services to the customer, valued at the amount that the entity expects to be entitled in exchanged for those goods or services.

Pursuant to IFRS 15, an entity should:

• identify customer contracts that fall within the scope of the new standard;

• identify the separate performance obligations in the contract based on the following criteria: (i) sales of goods or services, separately, (ii) sales that are dependent or interrelated with other products or services; and (iii) homogeneous and consistent sales pattern;

• determine the price of the transaction by applying the following considerations: (i) variable consideration and constraining estimates of variable consideration; (ii) the existence of a significant financing component in the contract; (iii) any non-cash consideration; and (iv) the consideration payable to the customer;

• allocate the transaction price to each separate performance obligation; and

• recognize revenue when (or as) each performance obligation is satisfied either over time or at a point in time.

The new IFRS 15 enhances disclosures of revenue. This standard must be applied for periods beginning on or after January 1, 2018, and early application is permitted. During the year of application, entities may apply the rule retrospectively or use a modified approach.

PEMEX will adopt IFRS 15 retrospectively with the cumulative effect of applying the new standard recognized at the date of initial adoption (January 1, 2018) as an adjustment to the opening balance of retained earnings or other component of equity, as applicable. Under this transition method, PEMEX elected to apply this standard retrospectively only to contracts that were not completed contracts at January 1, 2018. For contracts that have been completed before December 31, 2017, with revenues not fully recognized as of that date, the current accounting policies under IAS 18 will continue to apply when recognizing revenue of those contracts during 2018. For contracts that take effect from January 1, 2018, revenue will be recognized in accordance with IFRS 15.

F-33

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

As part of the implementation of IFRS 15, different types of revenue from contracts with customers have been identified, evaluated and documented, as well as the main changes in accounting policies that will be reflected as of January 1, 2018 with respect to new contracts. The main changes in accounting policies are as follows:

i. Sale of products with other services:

The adoption of IFRS 15 will affect the manner in which PEMEX records the sale of products including oil, refined products, gas, petrochemicals, fertilizers and other sales. Until December 31, 2017, freight and other services, for example were recognized separately from products sold. Under IFRS 15, revenue is recognized with respect to the performance obligation under the contract, and so certain services that are currently accounted for separately, will now be presented as a single performance obligation together with the sale of the product.

ii. Services:

Services include transportation and storage of hydrocarbons, petroleum, petrochemicals, refined products, gas, petrochemical derivatives and others.

Rental services and some transportation services are currently presented in the revenues from services line item in the income statement. In many cases of services with components of leases are less than one year operating leases. Revenues corresponding to leasing have not been presented separately from revenues from services.

Under IFRS 15, leases cannot be presented in the same line item as revenues from service. The main change in accounting policy will be the separation and presentation of service and lease components.

iii. Determination of the transaction price:

Refunds, discounts, quantity and quality claims (in favor or against) and penalties (to customers or PEMEX) or breaches related to the sale of certain products were previously recognized as revenues. However, under IFRS 15, revenues will only be recognized if it is highly probable that there will not be a significant reversal in the revenue received. As a result, PEMEX will put in place mechanisms to approximate the refunds, discounts, quantity and quality claims and penalties at the time that the control of the product is transferred.

Revenue recognition

Revenues are currently recognized when the risks and benefits of the product are transferred, which occurs when the customer picks up or receives the product at PEMEX´s facilities or at a specific point of sale, accepts the products and assumes the risks and benefits related to the transfer of ownership.

Under IFRS 15, revenues from sale of products are recognized when the contractual obligation is satisfied, and control of the products is transferred to the customer. There will be changes in the revenue recognition of gas sale and certain services from “one point in time” to “over time”. However, a significant change is not expected because in some cases the practical expedient “right to invoice” will be applied to measure progress towards completion of the transaction.

F-34

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

As of December 31, 2017, PEMEX did not identify any significant uncompleted contracts. As a result, PEMEX has determined that the changes to amounts in prior years will not be significant. Nonetheless, there will be important changes in accounting policies for contracts issued as of January 1, 2018.

b) IFRS 9, “Financial Instruments” (“IFRS 9”(2014))

In July 2014, the IASB finalized the accounting reform of financial instruments and issued IFRS 9 (revised in 2014), which contains the requirements for, a) the classification and measurement of financial assets and liabilities, b) impairment methodology, and c) general information about hedge accounting. IFRS 9 (revised in 2014) replaces IAS 39 Financial Instruments: Recognition and Measurement as of its effective date.

These requirements should be applied retrospectively and, as permitted by IFRS 9 transitional provisions, it is not necessary for companies to restate comparative figures. Any adjustment in the carrying amounts of the financial assets and liabilities at the transition date is recognized by affecting the cumulative effect in the initial opening period.

The classification criteria depends on a combination of two important factors:

i. the business model within the financial asses is held (the business model test); and

ii. the contractual cashflow of the financial asset (the SPPI test). Based on these two tests, the asset can be measured as follows:

• Amortized cost: Financial Instruments under a business model whose objective is only the collection of contractual cash flows which are composed of principal and interest payments and where there are no significant sales unjustified and fair value is not a key factor in the management of these financial assets and the characteristics of cash flows represent substantially a “basic loan agreement” or SPPI. Unjustified sales are different from sales related to an increase in the credit risk of an asset or unexpected financing needs.

• Fair value with changes through other comprehensive income (“FVOCI”): Financial Instruments in a business model whose objective is to obtain cash flows and the sale of those assets, where fair value is a key factor in its management. In addition, the characteristics of the contractual cash flows represent substantially a “basic loan agreement”.

• Fair value with changes through profit or loss (“FVPL”): Financial instruments in a business model whose objective is not the aforementioned models, where fair value is a key factor in the management of these assets, and the financial instruments whose contractual cash flow characteristics do not substantially represent a “basic loan agreement”.

IFRS also replaces the impairment model of IAS 39 (the “loss incurred model”) with a new impairment model called the “expected credit loss” model. This impairment model will be applicable to financial assets that are not measured at FVPL. Changes in fair value of financial assets through FVOCI to the point of disposal are recorded in OCI.

The expected credit loss recognized for impairment purposes under IFRS 9 will be equivalent to a 12-month reserve, except when the financial instrument presents a “significant increase in credit risk” or presents objective evidence of impairment, recognizing a reserve equivalent to the remaining life of the financial instrument, based on the definition of general approach under IFRS 9.

F-35

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

IFRS 9 Implementation and government strategy

PEMEX has established a multidisciplinary working group with the objective to adapt its processes to the new standard in relation to the classification and measurement of financial instruments and the impairment estimation of credit risk, ensuring that these processes have been applied and adopted in accordance with IFRS 9.

Regarding classification and measurement, PEMEX carried out an analysis of its financial assets in order to identify those that could trigger a change in the accounting methodology, due to the definition of the business model and a failure to satisfy the SPPI test.

IFRS 9 Implementation analysis

PEMEX has defined January 1, 2018 as the initial date of adoption of IFRS 9 “Financial Instruments” and according to the transitional standard in IFRS 9, PEMEX will not restate previous periods for comparison purposes and any difference that may arise as a result of the adoption of IFRS 9 between the previous carrying amount and the carrying amount at the beginning of the reporting period shall be recognized in accumulated results over the opening initial period.

PEMEX has concluded that most of its financial assets will continue to be classified in the same way:

	Classification
Assets	IAS 39	IFRS 9	Change
Cash and cash equivalents	FVPL	FVPL		No
Available—for—sale financial assets	FVOCI	FVOCI		No
Derivative financial instruments	FVPL	FVPL		No
Long—term notes receivable	Amortized Cost	Amortized Cost		No

Capital or debt instruments classified as available-for-sale financial assets will continue to be measured at FVOCI.

PEMEX has concluded that the financial assets most affected by the impairment estimate under the expected credit loss model will be its accounts receivables, in relation to PEMEX’s holding of the long-term notes issued by the Mexican Government. The evaluation of the possible impairment of the notes will be made using the general approach for calculating impairment of the notes will be made using the general approach for calculating impairment contemplated under IFRS 9.

PEMEX considers it probable that impairment losses increase and present more volatility for instruments under the new methodology of expected credit losses. Furthermore, PEMEX considers that most of its accounts receivable are short-term without a significant financial component, so the simplified approach will be applied.

The preliminary evaluation of PEMEX indicates that the application of the new impairment requirements of IFRS 9 as of December 31, 2017 will impact the accounts receivable reserves as of January 1, 2018. An increase between 39.0% and 51.1% is expected in the accounts receivable reserves as compared to impairment losses incurred in accordance with IAS 39.

F-36

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Hedge accounting

PEMEX, as part of the initial adoption, elected to continue applying the hedge accounting requirements of IAS 39 instead of IFRS 9. PEMEX uses DFI’s to cover the exposure of foreign currency risk, interest rate risk and fluctuations in the price of its products, but these contracts are not accounted for as designated hedges. DFI’s are initially recognized at fair value on the date the derivative contract is entered into and after initial recognition are measured again at fair value.

As a result, PEMEX has determined that the changes to amounts in prior years will not be significant.

c) Interpretation of IFRIC 22 “Foreign Currency Transactions and Advance Considerations” (IFRIC 22)

As of December 2016, IASB published an interpretation of IFRIC 22 developed by the International Financial Reporting Standards Interpretations Committee (the Interpretations Committee). The interpretation clarified when to recognize payments and collections of foreign currency transactions paid in advance.

According to the interpretations, an entity must recognize foreign currency transactions when:

i. there is consideration that is denominated or priced in a foreign currency;

ii. the entity recognizes a prepayment asset or a deferred income liability in respect of that consideration, in advance of the recognition of the related asset, expense or income; and

iii. the prepayment asset or deferred income liability is non-monetary.

The Interpretations Committee concluded that:

• The date of the transaction, for the purpose of determining the exchange rate, is the date of initial recognition of the non- monetary prepayment asset or deferred income liability.

• If there are multiple payments or receipts in advance, a date of transaction is established for each payment or receipt.

IFRIC 22 is effective for annual reporting periods beginning on or after January 1, 2018. Entities may apply the rule retrospectively, or prospectively, in accordance with IAS 8 with certain exemptions.

PEMEX believes that these standards will not have an impact on its consolidated financial statements.

Standards effective for periods beginning in 2019

a) IFRS 16, “Leases” (“IFRS 16”)

In January 2016, the IASB published a new accounting standard IFRS 16, which replaces IAS 17, “Leases and Guide interpretations.”

The main changes from the previous standard are:

• IFRS 16 provides a comprehensive model for the identification of the lease arrangements and their treatment in the financial statements of both lessees and lessors;

• the new standard applies a control model to the identification of leases, distinguishing between leases and service contracts on the basis of whether there is an identified asset controlled by the customer;

F-37

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

• the distinction between financial and operating leasing is removed, therefore, the assets and liabilities are recognized in respect of all leases, with some exceptions for short-term leases and leases of low-value assets; and

• the standard does not include significant changes to the requirements for accounting by lessors.

The standard is effective for annual periods beginning on or after January 1, 2019, with earlier application permitted for entities that have also adopted IFRS 15, “Revenue from Contracts with Customers.”

PEMEX has established a multidisciplinary working group with the objective to adapt its processes to the new standard in the following phases: (i) training, (ii) obtaining information, (iii) diagnostic, (iv) determination of initial adjustments and (v) integration of change. As of the date of these consolidated financial statements, the training phase for the accounting staff is complete and PEMEX is in the process of analyzing leasing contracts in order to determine necessary changes to its procedures and reports. PEMEX has not determined the impact of IFRS 16 on its net income (loss) for the year. PEMEX estimates that it will conclude the implementation of IFRS 16 in February 2019.

b) Annual improvements—2015-2017 Cycle

In December 2017, the IASB published “the Annual Improvements to the IFRS of the 2015-2017 Cycle” through which it clarifies the following IFRS:

• IFRS 3 Business Combinations and IFRS 11 Joint Arrangements

IFRS 3 Business Combinations clarifies how an entity should recognize an increase of its interest in a joint operation:

• When a party to a joint arrangement obtains control of a business that was a part of that joint arrangement, and where that party had assumed a portion of the rights to the assets and obligations to the liabilities of that business prior to the acquisition date, the acquisition will be considered a business combination that is achieved in stages. The acquiriting entity must therefore apply the requirements for a business combination achieved in stages, including by measuring its previously held interest in the joint arrangement.

• When a party participates in, but does not share in the control of a joint operation, and subsequently takes joint control of that joint operation, this will constitute the acquisition of a business and previously held interest in the joint operation are not measured.

• IAS 12 Income Tax

All income tax consequence of dividends (including payments on financial instruments classified as equity) are recognized consistently with the transactions that generated the distributable profits (i. e. in profit or loss, other comprehensive income or equity basis).

• IAS 23 Borrowing Costs

With respect to the treatment of costs for loans subject to capitalization, the amendments clarify that:

• To the extent that an entity borrows funds generally and uses them for the purpose of obtaining a qualifying asset, that entity shall determine the amount of borrowing costs eligible for

F-38

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

capitalization by applying a capitalization rate to the expenditures on that asset. The capitalization rate shall be the weighted average of the borrowing costs applicable to all borrowings of the entity that are outstanding during the period.

• However, an entity shall exclude from this calculation borrowing cost applicable to borrowing made specifically for the purpose of obtaining a qualifying asset until substantially all the activities necessary to prepare that asset for its intended used or sale are complete.

The amount of borrowing costs that an entity capitalizes during a period shall not exceed the amount of borrowing costs it incurred during that period.

The amendments are effective for annual periods beginning on or after January 1, 2019.

PEMEX is in the process of evaluating the impact that these amendments will have on its consolidated financial statements.

c) IFRIC 23—Uncertainty over Income Tax Treatments

In June 2017, the IASB published a new accounting interpretation to be applied to the determination of taxable profit (tax loss), tax bases, unused tax losses, unused tax credits and tax rates, where there is uncertainty over income tax treatments under IAS 12.

In order to make these tax assessments, an entity must consider whether it is probable that the relevant taxing authority will accept each tax treatment, or group of tax treatments, that the entity has used or plans to use in its next income tax filing:

• If the entity concludes that it is probable that a particular tax treatment will be accepted by the relevant taxing authority, that entity must determine taxable profit (tax loss), tax bases, unused tax losses, unused tax credits or tax rates consistently with the tax treatment included in its income tax filings.

• If the entity concludes that it is not probable that a particular tax treatment is accepted by the relevant taxing authority, the entity must use the most likely amount or the expected value of the tax treatment when determining taxable profit (tax loss), tax bases, unused tax losses, unused tax credits and tax rates. That calculation should be based on which method provides better predictions of the resolution of the uncertainty.

IFRIC 23 is effective for annual reporting periods beginning on or after January 1, 2019. Earlier application is permitted. PEMEX does not anticipate being impacted by IFRIC 23 because all tax positions are discussed and agreed with the SHCP prior to releasing quarterly or annual financial statements.

F-39

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

w. Reclassifications

Due to a significant loss of control over TAG Norte Holdings, S. de R.L. de C.V. and TAG Pipelines Sur, S. de R.L. de C.V., whose investment in these companies was presented in investments in joint ventures and associates in the past was reclassified to available-for-sale financial assets as of December 31, 2017. Accordingly the balance as of these investments as of December 31, 2016 was reclassified for purposes of improving its presentation the consolidated statements of financial position as follows:

	2016
Line item	As previously (reported)		Reclassification			Following reclassification
Available—for—sale financial assets		Ps.          435,556		Ps. 2,417,123			Ps.       2,852,679
Total current assets		355,398,800		2,417,123			357,815,923
Investments in joint ventures and associates		23,154,632		(2,417,123	)		20,737,509
Total non-current assets		1,974,487,224		(2,417,123	)		1,972,070,101

These reclassifications had no impact on PEMEX’s total assets.

Due to the fact that reinsurance premiums from KOT Insurance Company, AG., from which PEMEX derives revenue, are not part of the core services provided by PEMEX, they are included in other income (expenses), net. Therefore, for comparison purposes, the consolidated statements of comprehensive income for the years ended December 31, 2016 and 2015 were reclassified as follow:

	2016
Line item	As previously (reported)		Reclassification			Following reclassification
Services income		Ps.     14,427,081		Ps. (5,452,439	)		Ps.       8,974,642
Total of sales		1,079,545,671		(5,452,439	)		1,074,093,232
Cost of sales		867,580,634		(1,758,413	)		865,822,221
Gross income (loss)		543,279,380		(3,694,026	)		539,585,354
Other income (expenses), net		18,955,580		3,694,026			22,649,606

	2015
Line item	As previously (reported)			Reclassification			Following reclassification
Services income		Ps.     12,912,112			Ps. (4,602,077	)		Ps.       8,310,035
Total of sales		1,166,362,469			(4,602,077	)		1,161,760,392
Cost of sales		895,068,904			(3,104,298	)		891,964,606
Gross income (loss)		(114,474,036	)		(1,497,779	)		(115,971,815	)
Other income (expenses), net		(2,373,266	)		1,497,779			(875,487	)

These reclassifications had no impact on PEMEX’s net income.

F-40

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

In order to provide a better presentation in Duties, taxes and other, certain amounts in Income Tax line item, were reclassified to Hydrocarbon extraction duties and others line item, as follows:

	2016
Line item	As previously (reported)			Reclassification			Following reclassification
Hydrocarbon extraction duties and others		Ps.  304,813,375			Ps.  (27,651,571	)		Ps.  277,161,804
Income tax		(40,291,940	)		27,651,571			(12,640,369	)

These reclassifications had no impact on PEMEX’s net income.

NOTE 4. SUBSIDIARY ENTITIES AND SUBSIDIARY COMPANIES

As of December 31, 2017, the Subsidiary Entities consolidated in these financial statements include Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Cogeneration and Services, Pemex Drilling and Services, Pemex Logistics, Pemex Fertilizers and Pemex Ethylene.

The consolidated Subsidiary Companies are as follows:

• P.M.I. Marine, DAC. (PMI Mar) ⁽ⁱ⁾

• P.M.I. Services, B.V. (PMI SHO) ⁽ⁱ⁾

• P.M.I. Holdings, B.V. (PMI HBV) ^(i)(x)

• P.M.I. Trading, Ltd. (PMI Trading) ⁽ⁱ⁾

• PEMEX Internacional España, S. A. (PMI SES) ^(i)(viii)

• P.M.I. Holdings Petróleos España, S. L. (HPE) ⁽ⁱ⁾

• P.M.I. Services North America, Inc. (PMI SUS) ⁽ⁱ⁾

• P.M.I. Holdings North America, Inc. (PMI HNA) ^(i)(ix)

• P.M.I. Norteamérica, S. A. de C. V. (PMI NASA) ⁽ⁱ⁾

• P.M.I. Comercio Internacional, S. A. de C. V. (PMI CIM) ^(i)(ii)

• PMI Field Management Resources, S. L. (FMR) ^(i)(xi)

• PMI Campos Maduros SANMA, S. de R. L. de C. V. (SANMA) ⁽ⁱ⁾

• Pro-Agroindustria, S. A. de C. V. (AGRO)

• PMI Azufre Industrial, S. A. de C. V. (PMI AZIND) ⁽ⁱ⁾

• PMI Infraestructura de Desarrollo, S. A. de C. V. (PMI ID) ⁽ⁱ⁾

• PMI Cinturón Transoceánico Gas Natural, S. A. de C. V. (PMI CT) ⁽ⁱ⁾

• PMI Transoceánico Gas LP, S. A. de C. V. (PMI TG) ⁽ⁱ⁾

• PMI Servicios Portuarios Transoceánicos, S. A. de C. V. (PMI SP)

• PMI Midstream del Centro, S. A. de C. V. (PMI MC) ⁽ⁱ⁾

F-41

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

• PEMEX Procurement International, Inc. (PPI)

• Hijos de J. Barreras, S. A. (HJ BARRERAS) ⁽ⁱⁱ⁾

• PEMEX Finance, Ltd. (FIN) ⁽ⁱⁱ⁾

• Mex Gas Internacional, S. L. (MGAS)

• Pemex Desarrollo e Inversión Inmobiliaria, S. A. de C. V. (PDII)

• Kot Insurance Company, AG. (KOT)

• PPQ Cadena Productiva, S.L. (PPQCP)

• III Servicios, S. A. de C. V. (III Servicios)

• PMI Ducto de Juárez, S. de R.L. de C.V. (PMI DJ)^(i)(iii)

• PMX Cogeneración Internacional, S.L. (MG COG) ^{(iv)(vi)(xii)}

• PMX Cogeneración S.A.P.I. de C.V. (PMX COG)^{(iv) (xii)}

• PMX Fertilizantes Holding, S.A de C.V. (PMX FH) ^(iv)

• PMX Fertilizantes Pacífico, S.A. de C.V. (PMX FP) ^(iv)

• Grupo Fertinal (GP FER) ^(iv)

• Compañía Mexicana de Exploraciones, S.A. de C.V. (COMESA)^(v)

• P.M.I Trading Mexico, S.A. de C.V. (TRDMX) ^(vii)

• Holdings Holanda Services, B.V. (HHS) ^(x)

i. Member Company of the “PMI Subsidiaries”.

ii. Non-controlling Interest Company.

iii. As of January 2016, this company started operations and was included in the consolidated financial statements of PEMEX.

iv. As of June 2016, this company was included in the consolidated financial statements of PEMEX.

v. As of July 2016, this company was included in the consolidated financial statements of PEMEX.

vi. Until October 2016, formerly Mex Gas Cogeneración S.L.

vii. As of January 2017, this company started operations and was included in the consolidated financial statements of PEMEX

viii. As of February 2017, this company merged with HPE.

ix. As of June 2017, this company merged with SUS.

x. As of October 2017, PMI HBV was divided and HHS was created and included in the consolidated financial statements of PEMEX.

xi. This Company was liquidated.

xii. As of December 2017, PEMEX acquired shares in these companies and they were included in the consolidated financial statements of PEMEX.

NOTE 5. Segment financial information

PEMEX’s primary business is the exploration and production of crude oil and natural gas, as well as the production, processing, marketing and distribution of petroleum and petrochemical products. After the Corporate Reorganization, PEMEX’s operations have been conducted through nine business segments: exploration and production, industrial transformation, cogeneration and services, drilling and services, logistics, ethylene, fertilizers, the Trading Companies and corporate and other operating subsidiary companies. Due to PEMEX’s structure, there are significant quantities of inter-segment sales among the reporting segments, which are made at internal transfer prices established by PEMEX reflecting international market prices.

F-42

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The primary sources of revenue for PEMEX’s business segments are as described below:

• The exploration and production segment earns revenues from domestic sales of crude oil and natural gas, and from exporting crude oil through certain of the Trading Companies. Export sales are made through PMI CIM to approximately 32 major customers in various foreign markets. Approximately half of PEMEX’s crude oil is sold to Pemex Industrial Transformation.

• The industrial transformation segment earns revenues from sales of refined petroleum products and derivatives, mainly to third parties within the domestic market. This segment also sells a significant portion of the fuel oil it produces to the Comisión Federal de Electricidad (Federal Electricity Commission, or “CFE”) and a significant portion of jet fuel produced to Aeropuertos y Servicios Auxiliares (the Airports and Auxiliary Services Agency). The refining segment’s most important products are different types of gasoline and diesel.

• The industrial transformation segment also earns revenues from domestic sources generated by sales of natural gas, liquefied petroleum gas, naphtha, butane and ethane and certain other petrochemicals such as methane derivatives, ethane derivatives, aromatics and derivatives.

• The cogeneration segment receives income from the cogeneration, supply and sale of electricity and thermal energy and also provides technical and management activities associated with these services.

• The drilling segment receives income from drilling services, and servicing and repairing wells.

• The logistics segment earns income from transportation and storage of crude oil, petroleum products and petrochemicals, as well as related services, which it provides by employing pipelines and offshore and onshore resources, and from providing services related to the maintenance, handling, guarding and management of these products.

• The ethylene segment earns revenues from the distribution and trade of methane, ethane and propylene in the domestic market.

• The fertilizers segment earns revenues from trading ammonia, fertilizers and its derivatives, mostly in the domestic market.

• The trading companies segment, which consist of PMI CIM, PMI NASA, PMI Trading and MGAS (the “Trading Companies”), earn revenues from trading crude oil, natural gas and petroleum and petrochemical products in international markets.

• The segment related to corporate and other operating Subsidiary Companies provides administrative, financing, consulting and logistical services, as well as economic, tax and legal advice and re-insurance services to PEMEX’s entities and companies.

F-43

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The following tables present the condensed financial information of these segments, after elimination of unrealized intersegment gain (loss), and include only select line items. As a result, the line items presented below may not total. These reporting segments are those which PEMEX’s management evaluates in its analysis of PEMEX and on which it bases its decision-making.

As of/for the year ended December 31, 2017	Exploration and Production			Industrial Transformation			Cogeneration and Services(1)			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies			Intersegment eliminations			Total
Sales:
Trade	Ps.	—			Ps. 857,456,146		Ps.	—		Ps.	—		Ps.	—			Ps. 4,123,006			Ps. 12,621,648			Ps. 508,539,112			Ps. 3,159,238		Ps.	—			Ps. 1,385,899,150
Intersegment		762,637,362			150,360,283			114,233			3,400,456			70,671,871			642,965			1,565,757			539,193,190			79,031,944			(1,607,618,061	)		—
Services income		—			6,116,937			334,755			41,741			3,714,941			2,339			26,733			66,621			826,502			—			11,130,569
(Reversal) impairment of wells pipelines, properties, plant and equipment, net		129,350,315			15,952,092			—			—			—			1,935,500			—			—			4,206,653			—			151,444,560
Cost of sales		391,089,410			1,004,683,554			472,732			468,171			50,926,263			6,001,259			14,272,340			1,031,997,901			33,033,923			(1,528,740,673	)		1,004,204,880
Gross income (loss)		242,197,637			(6,702,280	)		(23,744	)		2,974,026			23,460,549			(3,168,449	)		(58,202	)		15,801,022			45,777,108			(78,877,388	)		241,380,279
Other revenues (expenses), net		10,204,045			1,515,538			2,646			(31,454	)		(24,134,436	)		9,013			23,030			307,212			(5,344,872	)		22,623,354			5,174,076
Distribution, transportation and sales expenses		—			26,049,566			13,581			—			73,526			528,370			334,663			375,482			59,043			(5,544,561	)		21,889,670
Administrative expenses		58,539,119			38,994,887			37,679			888,776			7,459,928			352,537			1,105,554			1,564,859			62,001,641			(51,005,526	)		119,939,454
Operating income (loss)		193,862,563			(70,231,195	)		(72,358	)		2,053,796			(8,207,341	)		(4,040,343	)		(1,475,389	)		14,167,893			(21,628,448	)		296,053			104,725,231
Financing income		121,293,404			11,427,907			147			57,313			1,622,827			2,248			46,113			905,405			145,907,795			(265,097,306	)		16,165,853
Financing cost		(136,378,338	)		(2,398,643	)		(19,882	)		(795,947	)		(2,307,427	)		(211,004	)		(1,964	)		(1,328,827	)		(239,003,771	)		264,801,255			(117,644,548	)
Derivative financial instruments (cost) income, net		(1,613,874	)		5,835			—			—			—			—			—			(772,143	)		27,718,506			—			25,338,324
Foreign exchange (loss) income, net		10,043,316			4,924,209			—			227,365			613,099			(20,925	)		(10,486	)		(4,318	)		7,411,862			—			23,184,122
Profit (loss) sharing in joint ventures and associates		(75,195	)		485,224			—			—			(74	)		—			—			1,049,809			(212,666,494	)		211,567,170			360,440
Taxes, duties and other		338,169,260			—			—			276,967			(7,444,967	)		—			—			1,972,718			6,063			—			332,980,041
Net (loss) income		(151,037,384	)		(55,786,663	)		(92,093	)		1,265,560			(833,949	)		(4,270,024	)		(1,441,726	)		12,045,101			(292,266,613	)		211,567,172			(280,850,619	)
Total current assets		1,036,063,541			570,380,888			179,807			6,871,148			49,391,784			3,155,476			3,994,381			158,414,445			506,187,594			(1,971,112,774	)		363,526,290
Investments in joint ventures and associates		64,328			4			—			—			18,336			—			—			15,805,506			(465,026,224	)		465,845,414			16,707,364
Wells, pipelines, properties, plant and equipment, net		945,945,889			286,423,735			—			18,956,882			119,647,553			5,713,998			19,008,822			6,739,231			34,073,216			—			1,436,509,326
Total assets		2,058,036,405			857,196,306			179,807			26,220,748			191,895,993			8,923,456			23,142,045			186,808,899			2,111,740,735			(3,332,142,280	)		2,132,002,114
Total current liabilities		284,656,058			459,130,165			531,580			2,201,936			44,521,371			6,455,246			2,183,654			112,046,527			1,439,097,882			(1,961,697,234	)		389,127,185
Long-term debt		1,826,843,268			25,437,147			—			11,258,734			2,814,640			—			—			2,712,654			1,837,690,559			(1,826,091,398	)		1,880,665,604
Employee benefits		372,032,958			588,573,518			—			333,212			1,842,892			98,361			105,033			(966,238	)		296,416,386			—			1,258,436,122
Total liabilities		2,570,412,398			1,077,108,748			531,580			13,886,424			56,706,251			6,556,050			2,308,890			116,842,881			3,587,988,972			(3,797,987,695	)		3,634,354,499
Equity (deficit), net		(512,375,993	)		(219,912,442	)		(351,773	)		12,334,324			135,189,742			2,367,406			20,833,155			69,966,018			(1,476,248,237	)		465,845,415			(1,502,352,385	)
Depreciation and amortization		127,742,568			17,935,112			—			2,368,123			4,562,140			422,930			1,688,493			(19,798	)		2,004,945			—			156,704,513
Net periodic cost of employee benefits		32,794,386			52,538,989			—			39,697			(4,954	)		(1,999	)		(12,561	)		16,166			22,703,351			—			108,073,075
Acquisition of wells, pipelines, properties, plant and equipment		67,845,989			14,678,182			—			418,283			5,189,409			219,152			475,196			321,145			4,832,461			—			93,979,817

(1) Certain of the assets of Pemex Cogeneration and Services have been transferred to Pemex Industrial Transformation.

F-44

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

As of/for the year ended December 31, 2016	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies			Intersegment eliminations			Total
Sales:
Trade	Ps.	—		Ps.	648,088,013		Ps.	—		Ps.	—		Ps.	—		Ps.	3,873,403		Ps.	15,392,552		Ps.	395,118,117		Ps.	2,646,505		Ps.	—		Ps.	1,065,118,590
Intersegment		616,380,615			117,096,378			51,913			1,981,754			68,316,958			900,464			1,764,438			405,293,283			50,683,175			(1,262,468,978	)		—
Services income		—			5,565,604			132,521			70,112			2,813,887			1,908			60,141			236,230			473,415			(379,176	)		8,974,642
(Reversal) impairment of wells pipelines, properties, plant and equipment, net		(271,709,433	)		(52,498,881	)		—			—			(5,829,520	)		—			(1,276,509	)		—			—			—			(331,314,343	)
Cost of sales		359,064,884			823,763,927			166,721			143,956			61,248,584			5,506,198			13,936,213			783,691,245			7,260,043			(1,188,959,550	)		865,822,221
Gross income (loss)		529,025,164			(515,051	)		17,713			1,907,910			15,711,781			(730,423	)		4,557,427			16,956,385			46,543,052			(73,888,604	)		539,585,354
Other revenues (expenses), net		27,346,794			19,964,654			—			591,704			(27,189,969	)		32,710			63,989			3,412,711			(906,183	)		(666,804	)		22,649,606
Distribution, transportation and sales expenses		—			50,792,317			8,232			6			148,215			185,168			481,727			229,432			49,162			(26,663,019	)		25,231,240
Administrative expenses		54,509,047			34,183,846			32,126			983,560			7,175,451			731,479			2,101,834			1,157,182			60,497,232			(48,718,224	)		112,653,533
Operating income (loss)		501,862,911			(65,526,560	)		(22,645	)		1,516,048			(18,801,854	)		(1,614,360	)		2,037,855			18,982,482			(14,909,525	)		825,835			424,350,187
Financing income		56,040,129			11,056,345			—			72,995			373,301			4,358			64,582			1,098,079			125,964,466			(180,925,000	)		13,749,255
Financing cost		(109,946,363	)		(3,188,892	)		(12,055	)		(642,711	)		(481,741	)		(20,217	)		(2,980	)		(1,342,351	)		(163,400,779	)		180,193,625			(98,844,464	)
Derivative financial instruments (cost) income, net		—			3,172			—			—			—			—			—			(1,951,959	)		(12,052,200	)		—			(14,000,987	)
Foreign exchange (loss) income, net		(217,166,718	)		(12,858,875	)		—			(1,570,317	)		(1,118,537	)		(29,263	)		(2,843	)		174,866			(21,441,056	)		—			(254,012,743	)
Profit (loss) sharing in joint ventures and associates		(21,164	)		649,520			—			—			—			—			—			1,586,503			(117,426,818	)		117,347,804			2,135,845
Taxes, duties and other		276,647,448			—			—			(481,581	)		(10,010,686	)		—			—			7,380,870			(9,014,616	)		—			264,521,435
Net (loss) income		(45,878,653	)		(69,865,290	)		(34,700	)		(142,404	)		(10,018,145	)		(1,659,482	)		2,096,614			11,166,750			(194,251,296	)		117,442,264			(191,144,342	)
Total current assets		983,260,710			795,237,287			388,422			6,032,213			22,087,801			1,724,967			5,817,262			125,081,531			613,881,578			(2,195,695,848	)		357,815,923
Investments in joint ventures and associates		139,523			257,159			—			—			—			—			—			17,568,893			(247,349,711	)		250,121,645			20,737,509
Wells, pipelines, properties, plant and equipment, net		1,176,504,263			311,432,174			—			21,023,629			86,695,514			7,771,634			20,086,650			6,691,813			37,536,571			—			1,667,742,248
Total assets		2,206,418,541			1,107,094,580			388,423			27,673,598			130,824,921			9,556,469			26,007,319			155,376,864			2,359,024,145			(3,692,478,836	)		2,329,886,024
Total current liabilities		340,011,451			666,467,674			472,236			3,894,121			19,824,792			2,995,088			3,879,828			78,894,485			1,497,612,971			(2,187,862,760	)		426,189,886
Long-term debt		1,737,109,328			31,495,027			—			12,489,423			4,382,109			—			—			3,597,938			1,757,315,685			(1,739,384,968	)		1,807,004,542
Employee benefits		362,312,386			575,277,374			191,876			441,127			571,702			20,362			21,893			(749,034	)		282,321,750			—			1,220,409,436
Total liabilities		2,533,221,665			1,278,138,290			664,829			16,853,202			29,336,417			3,015,450			3,901,722			86,885,889			3,553,477,189			(3,942,600,482	)		3,562,894,171
Equity (deficit), net		(326,803,124	)		(171,043,710	)		(276,406	)		10,820,396			101,488,504			6,541,019			22,105,597			68,490,975			(1,194,453,044	)		250,121,646			(1,233,008,147	)
Depreciation and amortization		124,329,921			17,425,472			—			2,559,357			2,230,557			481,241			1,395,232			86,707			1,931,004			—			150,439,491
Net periodic cost of employee benefits		32,617,215			52,886,397			5,860			31,491			30,340			(1,178	)		1,424			(552,735	)		24,719,602			—			109,738,416
Acquisition of wells, pipelines, properties, plant and equipment		70,418,370			32,254,531			—			2,053,139			26,344,495			889,420			1,724,690			1,019,484			21,031,214			—			155,735,343

F-45

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

As of/for the year ended December 31, 2015	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies			Intersegment eliminations			Total
Sales:
Trade	Ps.	—		Ps.	740,190,020		Ps.	—		Ps.	—		Ps.	—		Ps.	1,494,478		Ps.	4,551,413		Ps.	407,214,446		Ps.	—		Ps.	—		Ps.	1,153,450,357
Intersegment		690,642,133			126,294,195			—			1,511,970			598,853			209,970			473,990			353,137,149			18,296,515			(1,191,164,775	)		—
Services income		—			7,549,061			—			—			10,355,988			236			17,893			661,683			505,032			(10,779,858	)		8,310,035
Impairment of wells, pipelines, properties, plant and equipment		394,396,580			76,442,079			—			—			5,829,519			—			1,276,512			—			—			—			477,944,690
Benefit from change in pension plan		(46,368,308	)		(45,808,781	)		—			—			—			—			—			—			—			—			(92,177,089	)
Cost of sales		427,158,621			876,531,944			2,793			706,896			10,727,462			1,707,548			4,965,414			749,655,199			2,791,350			(1,182,282,621	)		891,964,606
Gross income (loss)		(84,544,760	)		(33,131,966	)		(2,793	)		805,074			(5,602,140	)		(2,864	)		(1,198,630	)		11,358,079			16,010,197			(19,662,012	)		(115,971,815	)
Other revenues (expenses), net		(7,957,202	)		1,243,040			—			38			26,941			14,680			19,909			1,666,783			2,219,539			1,890,785			(875,487	)
Distribution, transportation and sales expenses		—			35,292,527			1,448			—			3,009			4,416			62,071			428,613			254			(6,863,699	)		28,928,639
Administrative expenses		18,454,281			40,529,587			47,670			8,553			104,794			152,404			519,351			1,967,581			61,609,813			(10,921,939	)		112,472,095
Benefit from change in pension plan		(17,853,725	)		(39,975,450	)		—			—			—			—			—			—			(46,031,780	)		—			(103,860,955	)
Operating income (loss)		(93,102,518	)		(67,735,590	)		(51,911	)		796,559			(5,683,002	)		(145,004	)		(1,760,143	)		10,628,668			2,651,449			14,411			(154,387,081	)
Financing income		25,852,078			2,789,535			—			43,690			37			3,503			7,728			1,147,870			110,816,691			(125,670,273	)		14,990,859
Financing cost		(90,822,360	)		(13,738,104	)		2,110			(95,280	)		(61,153	)		—			—			(1,299,580	)		(87,289,616	)		125,530,390			(67,773,593	)
Derivative financial instruments (cost) income, net		—			6,463			—			—			—			—			—			1,347,323			(22,803,663	)		—			(21,449,877	)
Foreign exchange (loss), net		(132,165,427	)		(7,364,486	)		(7,509	)		(92,046	)		(11,090	)		(3,600	)		(2,802	)		(49,190	)		(15,069,424	)		—			(154,765,574	)
(Loss) profit sharing in joint ventures and associates		(473,082	)		671,868			—			—			—			—			—			2,056,259			(749,900,890	)		749,963,960			2,318,115
Taxes, duties and other		376,682,705			1,839,021			—			197,491			(2,069,848	)		—			—			5,134,176			(50,283,298	)		—			331,500,247
Net (loss) income		(667,394,014	)		(87,209,335	)		(57,310	)		455,432			(3,685,360	)		(145,101	)		(1,755,217	)		8,697,174			(711,312,155	)		749,838,488			(712,567,398	)
Total current assets		709,252,019			313,801,630			655,239			2,171,717			49,162,929			1,594,643			4,988,511			73,116,155			275,582,816			(1,163,125,162	)		267,200,497
Investments in joint ventures and associates		919,654			6,687,977			—			—			—			8,500			—			11,845,489			(242,233,405	)		246,937,384			24,165,599
Wells, pipelines, properties, plant and equipment, net		966,144,619			246,463,069			—			22,647,454			58,078,603			7,405,969			18,480,684			3,045,704			22,217,529			—			1,344,483,631
Total assets		1,698,909,240			567,486,579			655,240			24,917,981			111,307,038			9,034,376			23,705,118			93,266,620			1,443,189,885			(2,196,817,877	)		1,775,654,200
Total current liabilities		278,507,394			104,569,842			469,524			1,981,652			14,698,159			1,486,468			4,534,980			34,749,438			1,157,183,570			(1,154,773,306	)		443,407,721
Long-term debt		1,252,239,594			16,707,005			—			12,031,849			4,850,905			—			—			3,607,840			1,285,676,066			(1,274,240,092	)		1,300,873,167
Employee benefits		379,150,943			609,492,623			61,171			417,817			368,036			12,533			3,611			(59,581	)		289,938,288			—			1,279,385,441
Total liabilities		1,985,557,185			735,280,560			530,696			14,431,318			19,917,100			1,499,001			4,538,591			41,420,792			2,747,910,113			(2,443,755,258	)		3,107,330,098
Equity (deficit), net		(286,647,945	)		(167,793,981	)		124,544			10,486,663			91,389,938			7,535,375			19,166,527			51,845,828			(1,304,720,228	)		246,937,381			(1,331,675,898	)
Depreciation and amortization		144,567,149			20,916,796			—			612,741			337,364			158,505			442,504			84,493			831,698			—			167,951,250
Net periodic cost of employee benefits		23,608,485			21,392,600			(298	)		—			(310	)		—			—			(119,819	)		17,668,484			—			62,549,142
Acquisition of wells, pipelines, properties, plant and equipment		184,786,051			68,935,841			—			—			1,544,224			320,762			1,882,108			677,314			6,711,511			—			264,857,811

F-46

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

PEMEX’s management measures the performance of the segments based on operating income and net segment income before elimination of unrealized intersegment gain (loss), as well as by analyzing the impact of the results of each segment on the consolidated financial statements. For certain of the items in these consolidated financial statements to conform with the individual financial statements of the operating segments, they must be reconciled. The tables below present the financial information of PEMEX’s operating segments, before intersegment eliminations:

The following tables present accounting reconciliations between individual and consolidated information.

As of/for the year ended December 31, 2017	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies
Sales:
By segment		Ps.   762,637,362			1,015,157,118			448,988			6,679,132			74,386,812			4,795,196			14,214,138			1,047,874,453			83,017,684
Less unrealized intersegment sales		—			(1,223,752	)		—			(3,236,935	)		—			(26,886	)		—			(75,530	)		—
Total consolidated sales		Ps.   762,637,362			1,013,933,366			448,988			3,442,197			74,386,812			4,768,310			14,214,138			1,047,798,923			83,017,684
Operating income (loss):
By segment		Ps.   194,814,292			(59,989,652	)		(72,358	)		882,692			(61,696,313	)		(7,148,431	)		(4,698,838	)		14,490,017			(21,628,448	)
Less unrealized intersegment sales		—			(1,223,752	)		—			(3,236,935	)		—			(26,886	)		—			(75,530	)		—
Less unrealized gain due to production cost valuation of inventory		(496,329	)		(9,017,791	)		—			2,932,663			—			—			—			(246,594	)		—
Less capitalized refined products		(574,381	)		—			—			—			—			—			—			—			—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			—			—
Less depreciation and impairment of revaluated transferred assets		—			—			—			1,475,376			53,488,972			3,134,974			3,223,449			—			—
Total consolidated operating income (loss)		Ps.   193,862,563			(70,231,195	)		(72,358	)		2,053,796			(8,207,341	)		(4,040,343	)		(1,475,389	)		14,167,893			(21,628,448	)
Net income (loss):
By segment		Ps. (150,388,699	)		(44,599,751	)		(358,862	)		345,913			(40,300,942	)		(8,616,130	)		(5,866,542	)		5,200,268			(292,266,613	)
Less unrealized intersegment sales		—			(1,223,752	)		—			(3,236,935	)		—			(26,886	)		—			(75,530	)		—
Less unrealized gain due to production cost valuation of inventory		(496,329	)		(9,017,791	)		—			2,932,663			—			—			—			(246,594	)		—
Less capitalized refined products		(574,381	)		—			—			—			—			—			—			—			—
Less equity method elimination		303,044			(945,369	)		266,769			—			333			1,238,018			1,201,367			7,166,957			—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			—			—
Less depreciation and impairment of revaluated transferred assets, net of deferred taxes		—			—			—			1,223,919			39,466,660			3,134,974			3,223,449			—			—
Total consolidated net (loss) income		Ps. (151,037,384	)		(55,786,663	)		(92,093	)		1,265,560			(833,949	)		(4,270,024	)		(1,441,726	)		12,045,101			(292,266,613	)

F-47

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

As of/for the year ended December 31, 2017	Exploration and Production			Industrial Transformation			Cogeneration and Services		Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies
Assets:
By segment		Ps. 2,084,553,745			912,770,881			179,807		28,256,876			276,537,764			17,689,305			35,498,783			195,538,239			2,111,740,735
Less unrealized intersegment sales		858,094			(5,389,977	)		—		—			7,183			—			(5,303	)		(408,059	)		—
Less unrealized gain due to production cost valuation of inventory		(3,657,242	)		(42,379,229	)		—		—			—			(26,886	)		—			(7,163,664	)		—
Less capitalized refined products		(574,381	)		—			—		—			—			—			—			—			—
Less depreciation and impairment of revaluated transferred assets, net of deferred taxes		(22,503,168	)		—			—		(2,036,128	)		(84,557,831	)		(2,165,068	)		(9,522,686	)		(424,849	)		—
Less equity method for unrealized profits		(759,624	)		(7,813,492	)		—		—			(91,123	)		(6,573,895	)		(2,828,749	)		(732,768	)		—
Less amortization of capitalized interest		118,981			8,123			—		—			—			—			—			—			—
Total consolidated assets		Ps. 2,058,036,405			857,196,306			179,807		26,220,748			191,895,993			8,923,456			23,142,045			186,808,899			2,111,740,735
Liabilities:
By segment		Ps. 2,570,412,398			1,081,528,677			531,580		13,186,297			56,706,251			6,556,050			2,308,890			116,648,398			3,587,988,972
Less unrealized intersegment sales		—			(4,419,929	)		—		700,127			—			—			—			194,483			—
Total consolidated liabilities		Ps. 2,570,412,398			1,077,108,748			531,580		13,886,424			56,706,251			6,556,050			2,308,890			116,842,881			3,587,988,972

F-48

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

As of/for the year ended December 31, 2016	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies
Sales:
By segment		Ps. 616,380,615			771,597,427			184,434			6,263,093			71,130,845			4,775,775			17,217,131			800,979,076			53,803,095
Less unrealized intersegment sales		—			(847,432	)		—			(4,211,227	)		—			—			—			(331,446	)		—
Total consolidated sales		Ps. 616,380,615			770,749,995			184,434			2,051,866			71,130,845			4,775,775			17,217,131			800,647,630			53,803,095
Operating income (loss):
By segment		Ps. 503,679,153			(60,347,367	)		(22,645	)		1,271,202			(25,701,065	)		(2,877,725	)		(3,504,812	)		19,526,997			(14,909,525	)
Less unrealized intersegment sales		—			(847,432	)		—			(4,211,227	)		—			—			—			(331,446	)		—
Less unrealized gain due to production cost valuation of inventory		(273,237	)		3,572,498			—			3,815,371			—			905,910			(2,163	)		(213,069	)		—
Less capitalized refined products		(1,661,986	)		(7,904,259	)		—			—			—			—			—			—			—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			—			—
Less depreciation and impairment of revaluated assets		—			—			—			640,702			6,899,211			357,455			5,544,830			—			—
Total consolidated operating income (loss)		Ps. 501,862,911			(65,526,560	)		(22,645	)		1,516,048			(18,801,854	)		(1,614,360	)		2,037,855			18,982,482			(14,909,525	)
Net income (loss):
By segment		Ps. (44,069,001	)		(61,639,067	)		(381,214	)		(387,250	)		(16,917,356	)		(7,820,835	)		(3,780,706	)		11,711,265			(194,251,296	)
Less unrealized intersegment sales		—			(847,432	)		—			(4,211,227	)		—			—			—			(331,446	)		—
Less unrealized gain due to production cost valuation of inventory		(273,237	)		3,572,498			—			3,815,371			—			905,910			(2,163	)		(213,069	)		—
Less capitalized refined products		(1,661,986	)		(7,904,259	)		—			—			—			—			—			—			—
Less equity method elimination		6,590			(3,047,030	)		346,514			—			—			4,897,988			334,653			—			—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			—			—
Less depreciation of revaluated assets		—			—			—			640,702			6,899,211			357,455			5,544,830			—			—
Total consolidated net (loss) income		Ps. (45,878,653)			(69,865,290	)		(34,700	)		(142,404	)		(10,018,145	)		(1,659,482	)		2,096,614			11,166,750			(194,251,296	)

F-49

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

As of/for the year ended December 31, 2016	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies
Assets: By segment		Ps.2,232,052,453			1,151,907,566			425,141			30,990,147			254,615,026			10,421,225			43,067,636			170,782,928			2,359,024,145
Less unrealized intersegment sales		483,230			(4,158,101	)		—			—			—			—			(5,304	)		(332,529	)		—
Less unrealized gain due to production cost valuation of inventory		(3,246,782	)		(33,361,438	)		—			—			—			—			—			(5,688,341	)		—
Less capitalized refined products		(1,661,986	)		—			—			—			—			—			—			—			—
Less depreciation of revalued assets		(20,585,300	)		—			—			(3,316,549	)		(123,790,105	)		(5,300,044	)		(12,746,136	)		(652	)		—
Less equity method for unrealized profits		(742,055	)		(7,293,447	)		(36,718	)		—			—			4,435,288			(4,308,877	)		(8,960,344	)		—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			(424,198	)		—
Total consolidated assets		Ps.2,206,418,541			1,107,094,580			388,423			27,673,598			130,824,921			9,556,469			26,007,319			155,376,864			2,359,024,145
Liabilities:
By segment		Ps.2,533,221,665			1,282,558,220			664,829			16,457,347			29,336,417			3,015,450			3,901,722			85,392,123			3,553,477,189
Less unrealized intersegment sales		—			(4,419,930	)		—			395,855			—			—			—			1,493,766			—
Total consolidated liabilities		Ps.2,533,221,665			1,278,138,290			664,829			16,853,202			29,336,417			3,015,450			3,901,722			86,885,889			3,553,477,189

F-50

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

As of/for the year ended December 31, 2015	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services		Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies
Sales:
By segment	Ps.	690,642,133			874,630,488			—			1,511,970		10,954,841			1,704,684			5,048,600			761,213,475			18,801,547
Less unrealized intersegment sales		—			(597,212	)		—			—		—			—			(5,304	)		(200,197	)		—
Total consolidated sales	Ps.	690,642,133			874,033,276			—			1,511,970		10,954,841			1,704,684			5,043,296			761,013,278			18,801,547
Operating income (loss):
By segment	Ps.	(89,473,302	)		(88,819,558	)		(51,911	)		700,748		(6,875,252	)		(262,145	)		(2,288,747	)		10,334,138			2,651,449
Less unrealized intersegment sales		—			(597,212	)		—			—		—			—			(5,304	)		(200,197	)		—
Less unrealized gain due to production cost valuation of inventory		(251,995	)		21,681,180			—			—		—			—			2,163			494,727			—
Less capitalized refined products		(3,496,201	)		—			—			—		—			—			—			—			—
Less amortization of capitalized interest		118,980			—			—			—		—			—			—			—			—
Less depreciation and impairment of revaluated assets		—			—			—			95,811		1,192,250			117,141			531,745			—			—
Total consolidated operating (loss) income	Ps.	(93,102,518	)		(67,735,590	)		(51,911	)		796,559		(5,683,002	)		(145,004	)		(1,760,143	)		10,628,668			2,651,449
Net income (loss):
By segment	Ps.	(663,719,119	)		(107,164,261	)		(57,310	)		359,621		(4,877,610	)		(262,242	)		(2,314,774	)		8,402,644			(711,312,155	)
Less unrealized intersegment sales		—			(597,212	)		—			—		—			—			(5,304	)		(200,197	)		—
Less unrealized gain due to production cost valuation of inventory		(251,995	)		21,681,180			—			—		—			—			2,163			494,727			—
Less capitalized refined products		(3,496,201	)		—			—			—		—			—			—			—
Less equity method elimination		(45,679	)		(1,129,042	)		—			—		—			—			30,953			—			—
Less amortization of capitalized interest		118,980			—			—			—		—			—			—			—			—
Less depreciation of revaluated assets		—			—			—			95,811		1,192,250			117,141			531,745			—			—
Total consolidated net (loss) income	Ps.	(667,394,014	)		(87,209,335	)		(57,310	)		455,432		(3,685,360	)		(145,101	)		(1,755,217	)		8,697,174			(711,312,155	)

F-51

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Supplemental geographic information:

	For the years ended December 31,
	2017		2016		2015
Domestic sales	Ps.	877,360,038	Ps.	670,000,473	Ps.	746,235,912
Export sales:
United States		302,912,999		221,954,461		266,826,499
Canada, Central and South America		13,943,080		14,058,897		11,027,813
Europe		71,470,613		64,348,997		58,707,787
Other		120,212,420		94,755,762		70,652,346
Total export sales		508,539,112		395,118,117		407,214,445
Services income		11,130,569		8,974,642		8,310,035
Total sales	Ps.	1,397,029,719	Ps.	1,074,093,232	Ps.	1,161,760,392

PEMEX does not have significant long-lived assets outside of Mexico.

The following table shows income by product:

	For the years ended December 31,
	2017		2016		2015
Domestic sales
Refined petroleum products and derivatives (primarily gasolines)		Ps. 784,048,048		Ps. 578,718,674		Ps. 660,573,780
Gas		70,930,855		59,648,576		54,497,824
Petrochemical products		22,381,135		31,633,223		31,164,308
Total domestic sales		Ps. 877,360,038		Ps. 670,000,473		Ps. 746,235,912
Export sales
Crude oil		Ps. 380,461,147		Ps. 288,625,794		Ps. 288,170,451
Refined petroleum products and derivatives (primarily gasolines)		109,615,457		92,705,248		118,129,615
Gas		21,675		20,995		27,283
Petrochemical products		18,440,833		13,766,080		887,096
Total export sales		Ps. 508,539,112		Ps. 395,118,117		Ps. 407,214,445

F-52

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

NOTE 6. CASH, CASH EQUIVALENTS AND RESTRICTED CASH

a. As of December 31, 2017 and 2016, cash and cash equivalents were as follows:

	2017		2016
Cash on hand and in banks(i)	Ps.	55,871,127	Ps.	71,430,427
Highly liquid investments(ii)		41,980,627		92,102,086
	Ps.	97,851,754	Ps.	163,532,513

(i) Cash on hand and in banks is primarily composed of cash in banks.

(ii) Mainly composed of short-term Mexican Government investments.

b. At December 31, 2017 and 2016, restricted cash was as follows:

	2017		2016
Restricted cash		Ps.               —	Ps.	10,478,626

Restricted cash as of December 31, 2016 was primarily composed of the deposit made by Pemex Exploration and Production in the amount of U.S. $465,060, plus interests as a result of an arbitration claim filed by Corporación Mexicana de Mantenimiento Integral, S. de R.L. de C.V. (“COMMISA”) before the International Court of Arbitration of the International Chamber of Commerce (the “ICA”). On April 6, 2017, Pemex Exploration and Production and Petróleos Mexicanos executed a settlement agreement with COMMISA and agreed to pay COMMISA U.S. $435,000, plus the applicable VAT with the funds deposited by Pemex Exploration and Production in a bank account as a guarantee before the U.S. District Court for the Southern District of New York and through a wire transfer.

During 2016, PMI HBV made deposits of U.S. $41,319, in an account in Banco Santander, S.A. as additional collateral for a credit agreement in accordance with the terms of the agreement. The credit agreement required that PMI HBV maintain a loan-to-value ratio based on the ratio between the principal amount of debt and the market value in U.S. dollars of the Repsol S. A. (“Repsol”) shares owned by PMI HBV. Due to the increase in the value of Repsol shares, the deposit was reimbursed to PMI HBV; therefore, beginning June 30, 2017, no restricted cash was held. On October 20, 2017, PMI HBV prepaid the balance of the credit agreement in order to sell all of its shares in Repsol.

NOTE 7. ACCOUNTS RECEIVABLE, NET

As of December 31, 2017 and 2016, accounts receivable and other receivables were as follows:

	2017		2016
Domestic customers, net	Ps.	60,057,141	Ps.	41,884,579
Export customers, net		54,428,883		34,859,341
Sundry debtors		26,105,703		18,736,922
Taxes to be recovered and prepaid taxes		23,039,023		29,361,303
Employees and officers		5,681,478		6,054,251
Advances to suppliers		1,250,846		2,246,437
Other accounts receivable		82,160		77,694
	Ps.	170,645,234	Ps.	133,220,527

F-53

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The following table shows a breakdown of accounts receivable based on their credit history at December 31, 2017 and 2016:

	Domestic customers
	2017			2016
1 to 30 days	Ps.	10,188,070			Ps.1,767,718
31 to 60 days		4,081,862			658,456
61 to 90 days		777,409			263,447
More than 90 days(i)		11,345,933			1,016,553
Past due		26,393,274			3,706,174
Impaired (reserved)		(951,932	)		(458,428	)
Unimpaired		25,441,342			3,247,746
Current		34,615,799			38,636,833
Total	Ps.	60,057,141			Ps.41,884,579

⁽ⁱ⁾ The increase in 2017 in accounts receivable invoices more than 90 days old is primarily due to the termination of the outstanding balances compensation system in place between Mexican Government owned companies.

	Export customers
	2017			2016
1 to 30 days	Ps.	334,155		Ps.	341,184
31 to 60 days		—			6,824
61 to 90 days		—			35,372
More than 90 days		315,888			624,157
Past due		650,043			1,007,537
Impaired (reserved)		(272,813	)		(374,699	)
Unimpaired		377,230			632,838
Current		54,051,653			34,226,503
Total	Ps.	54,428,883		Ps.	34,859,341

F-54

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Additionally, the reconciliation for impaired accounts receivable is as follows:

	Domestic customers
	2017			2016
Balance at the beginning of the year		Ps. (458,428	)		Ps. (667,883	)
Additions against income		(493,514	)		(218,836	)
Amount used		10			428,291
Balance at the end of the year		Ps. (951,932	)		Ps. (458,428	)
	Export customers
	2017			2016
Balance at the beginning of the year		Ps. (374,699	)		Ps. (312,004	)
Additions against income		(204,713	)		(25,931	)
Amount used		297,047			—
Translation effects		9,552			(36,764	)
Balance at the end of the year		Ps. (272,813)			Ps. (374,699)

NOTE 8. INVENTORIES, NET

As of December 31, 2017 and 2016, inventories were as follows:

	2017		2016
Refined and petrochemicals products		Ps. 27,862,384		Ps. 21,534,846
Products in transit		19,112,606		7,735,163
Crude oil		11,445,780		11,391,310
Materials and products in stock		5,172,779		4,721,834
Materials in transit		180,711		419,547
Gas and condensate products		84,670		89,360
		Ps. 63,858,930		Ps. 45,892,060

NOTE 9. HELD—FOR—SALE NON-FINANCIAL ASSETS

Pursuant to Round Zero, PEMEX was provisionally assigned titles to certain blocks in escrow. The ownership of the fixed assets located in those blocks is transferred when the blocks are awarded to third parties in subsequent rounds.

As a result of the Energy Reform Decree, the secondary legislation and the corresponding initial adjudication of rights for the exploration and extraction of oil and solid hydrocarbons addressed in transitory article 6 of the Energy Reform Decree, certain assignments that Pemex Exploration and Production received from the Mexican Government were affected. The Mexican Government will compensate PEMEX for these investments at fair value pursuant to the terms determined by the Ministry of Energy.

F-55

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

In 2016, pursuant to Round 1.3, the Ministry of Energy awarded certain contractual areas for the exploration and extraction of oil and solid hydrocarbons to third parties and their respective fixed assets have been transferred from PEMEX to such third parties. During 2016, PEMEX submitted the application for compensation from the Ministry of Energy for the fixed assets located in those areas, receiving resolution in 2017.

All the assets that are part of unassigned areas to PEMEX as part of Round Zero continue to be classified as long-lived assets, subject to all regulations applicable to such assets, provided PEMEX (1) obtains the economic benefits derived from the use thereof and (2) at the same time exercises control over them and assumes the benefits and risks associated with such assets.

Assets that are part of the areas that were not assigned to PEMEX as part of Round Zero, and from which PEMEX does not obtain economic benefits derived from use of such assets, are written down, affecting the results for that year.

As a result, of the Ps. 7,460,674 held-for-sale, the non-financial assets at December 31, 2016, Ps.4,652,314 were reclassified to fixed assets and the remaining Ps. 2,808,360, were transferred to the results of the year.

NOTE 10. AVAILABLE—FOR—SALE—FINANCIAL ASSETS

a. On January 1, 2016, PEMEX had a total of 20,724,331 shares of Repsol valued at Ps. 3,944,696, which represented approximately 1.48% of Repsol’s share capital.

On January 15, 2016, PMI HBV received 942,015 new Repsol shares valued at Ps. 188,490 as an in-kind dividend that was declared on December 31, 2015.

On June 13, 2016, Repsol declared flexible dividends to its shareholders, of which PMI HBV received 555,547 new Repsol shares as an in-kind dividend on July 18, 2016, valued at Ps. 128,051.

Since the 1,497,562 new Repsol shares were received as an in-kind dividend during 2016, they were not included in the loan agreement obtained by PMI HBV in August 2015 and these shares are presented as short-term available-for-sale financial assets amounting to Ps. 435,556. These shares were sold in January 2017.

On December 14, 2016, Repsol declared flexible dividends to its shareholders, of which PMI HBV received 584,786 new Repsol shares as an in-kind dividend in January 23, 2017. This amount was recognized as an account receivable of Ps.165,346 as of December 31, 2016.

As of December 31, 2016, the investment in 20,724,331 shares of Repsol held by PMI HBV was valued at Ps. 6,027,540. These shares are presented under non-current assets. The effect of the valuation on the investment at fair value was recorded in other comprehensive result in the consolidated statement of changes in equity (deficit) as a profit of Ps. 207,817 at December 31, 2016.

On January 24, 2017 and January 25, 2017, PMI HBV sold a total of 2,082,348 Repsol shares at an average price of € 14.17 per share, for a total amount of Ps. 684,029. These shares were not included as collateral on the loan agreement.

On June 7, 2017, Repsol declared flexible dividends to its shareholders, of which PMI HBV received 609,539 new Repsol shares as an in-kind dividend on July 13, 2017. This amount was recognized as an account receivable of Ps. 180,729.

F-56

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

On October 26, 2017, PMI HBV sold 21,333,870 Repsol shares for a total amount of Ps. 7,342,807 pursuant to a share forward transaction with Credit Agricole CIB. This sale, together with the sale on January 24 and 25, 2017, resulted in a total loss of Ps. 3,523,748.

As a result of the above, PEMEX does not have an equity interest in Repsol as of December 31, 2017. The 2016 balance allocated in other comprehensive income for Ps. 5,564,130 was transferred to the results of the year.

b. As of December 31, 2016, due to the loss of significant influence in TAG Norte Holding, S. de R. L. de C. V. and TAG Pipelines Sur, S. de R. L. de C. V., these companies were valued at fair value and are presented as short-term available-for-sale financial assets in the amount of Ps.2,417,123.

As of December 31, 2017, PEMEX is in the process of selling its shares of TAG Norte Holding, S. de R.L. de C.V. and TAG Pipeline Sur, S. de R.L. de C.V. These shares have been classified as available-for-sale-financial-assets and have been valued at their net realizable value, which as of December 31, 2017 has resulted in a negative value that has been recognized in the profit or loss at the end of the year. As of the date of these consolidated financial statements, PEMEX is in the process of selling these shares. As of December 31, 2017, available-for-sale current non-financial assets amounted Ps. 1,056,918.

NOTE 11. INVESTMENTS IN JOINT VENTURES AND ASSOCIATES

The investments in joint ventures and associates as of December 31, 2017 and 2016, were as follows:

		Percentage of investment		December 31,
				2017		2016
Deer Park Refining Limited			49.99%		Ps.14,405,542		Ps.14,039,384
Petroquímica Mexicana de Vinilo, S. A. de C. V.	(i)		44.09%		—		4,309,050
Sierrita Gas Pipeline LLC			35.00%		1,084,169		1,112,338
Frontera Brownsville, LLC.			50.00%		471,085		478,414
CH4 Energía, S. A.			50.00%		315,713		194,868
Texas Frontera, LLC.			50.00%		239,782		260,828
Administración Portuaria Integral de Dos Bocas, S.A. de C.V.			40.00%		64,328		139,523
PMV Minera, S.A. de C.V.			44.09%		45,133		61,779
Ductos el peninsular, S.A.P.I de C. V.			50.00%		18,336		18,626
Other-net			Various		63,276		122,699
					Ps.16,707,364		Ps.20,737,509

i. On April 20, 2016, an explosion occurred in the “Planta de Clorados 3” (Chlorinated Plant 3) of the Petroquímica Mexicana de Vinilo, resulting in approximately U.S. $ 461,000 in damages. Chorinated Plant 3 incurred the greatest amount of damage, including the loss of certain assets and the closure of the plant for an undefined amount of time. The Chlorine-Soda plants and the ethylene plants did not register any damage. On December 20, 2017, Petroquímica Mexicana de Vinilo permanently closed the plant, and -the full book value was written-off impacting the value of this investment.

F-57

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Profit (loss) sharing in joint ventures and associates:

	2017			2016			2015
Deer Park Refining Limited		Ps. 920,409			Ps. 1,437,850			Ps. 1,913,835
Ductos y Energéticos del Norte, S.A. de C.V.(i)		360,092			—			—
CH4 Energía S.A. de C.V.		125,132			—			—
Sierrita Gas Pipeline LLC		129,401			105,825			152,445
PMV Minera, S.A. de C.V.		6,253			—			—
Petroquímica Mexicana de Vinilo, S. A. de C. V.		(1,223,640	)		(190,468	)		(61,952	)
Administración Portuaria Integral de Dos Bocas, S.A. de C.V.		(75,195	)		—			—
Gasoductos de Chihuahua, S. de R. L. de C. V. (ii)		—			638,126			666,779
Compañía Mexicana de Exploraciones, S. A. de C. V.(iii)		—			—			(496,774	)
Other, net		117,988			144,512			143,782
Profit sharing in joint ventures and associates, net		Ps. 360,440			Ps. 2,135,845			Ps. 2,318,115

i. In November 2017, PEMEX sold its 50% interest in Ductos y Energéticos del Norte, S. de R.L. de C. V., to Infraestructura Energética Nova, S.A.B. of C.V. for a total of U.S. $ 3,141,710, yielding a profit of Ps. 3,139,103.

ii. On September 28, 2016, PEMEX completed the divestiture of its 50% ownership interest in the Gasoductos de Chihuahua S. de R.L. de C.V. joint venture with Infraestructura Energética Nova, S.A.B. de C.V. The stock was sold for Ps. 22,684,736, yielding a profit of Ps. 15,211,039.

iii. Beginning July 1, 2016 this company was included in the consolidated financial statements of PEMEX. Until June 30, 2016 this Company was accounted for as an investment in an associate under the equity method (see Note 3-a).

The following tables show condensed financial information of major investments recognized under the equity method during 2017 and 2016:

Condensed statements of financial position
	Deer Park Refining Limited				Sierrita Gas Pipeline, LLC
	2017		2016		2017		2016
Total assets		Ps. 41,075,547		Ps. 42,428,275		Ps.3,518,036		Ps.3,244,811
Total liabilities		Ps. 12,261,581		Ps. 14,346,643		Ps.   420,410		Ps.     66,703
Total equity		28,813,966		28,081,632		3,097,626		3,178,108
Total liabilities and equity		Ps.41,075,547		Ps. 42,428,275		Ps.3,518,036		Ps.3,244,811

F-58

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Condensed statements of comprehensive income

Deer Park Refining Limited

Sierrita Gas Pipeline, LLC

Gasoductos de Chihuahua, S. de R. L. de C. V.

December 31,

December 31,

August 31,

December 31,

2017

2016

2015

2017

2016

2016

2015

Sales and other income

Ps.16,427,064

Ps.16,750,155

Ps.16,658,705

Ps. 840,414

Ps. 717,351

Ps.3,798,666

Ps.4,617,982

Costs and expenses

14,586,061

13,874,172

12,830,653

470,697

414,994

2,522,415

3,284,424

Net result

Ps. 1,841,003

Ps. 2,875,983

Ps. 3,828,052

Ps. 369,717

Ps. 302,357

Ps.1,276,251

Ps.1,333,558

Additional information about the significant investments in joint ventures and associates is presented below:

• Deer Park Refining Limited. On March 31, 1993, PMI NASA acquired 50% of the Deer Park Refinery. In its capacity as general partner of Deer Park Refining Limited Partnership, Shell is responsible for the operation and management of the refinery, the purpose of which is to provide oil refinery services to PMI NASA and Shell for a processing fee. Shell is responsible for determining the crude oil and production materials requirements and both partners are required to contribute in equal amounts. Deer Park returns to PMI NASA and Shell products in the same amounts. Shell is responsible for purchasing the total amount of finished products in stock at market prices. This joint venture is recorded under the equity method.

• Petroquímica Mexicana de Vinilo, S.A. de C.V. On September 13, 2013, Pemex-Petrochemicals (now Pemex Industrial Transformation), through its subsidiary PPQ Cadena Productiva, S.L. and Mexichem founded Petroquímica Mexicana de Vinilo, S.A. de C.V. (Mexicana de Vinilo). The principal activity of Petroquímica Mexicana de Vinilo, S.A. de C.V. is the production and sale of chemicals. Mexicana de Vinilo’s main products are chlorine, caustic soda, ethylene and monomers of vinyl chloride. Mexichem has been responsible for operational and financial decisions for Petroquímica Mexicana de Vinilo. This investment is recorded under the equity method. Due to the damage caused by an accident that occurred in April 2016, Petroquímica Mexicana de Vinilo decided to permanently close the plant.

• Sierrita Gas Pipeline LLC. This company was created on June 24, 2013. Its main activity is the developing of projects related to the transportation infrastructure of gas in the United States. This investment is recorded under the equity method.

• Frontera Brownsville, LLC. Effective April 1, 2011, PMI SUS entered into a joint venture with TransMontaigne Operating Company L.P (TransMontaigne) to create Frontera Brownsville, LLC. Frontera Brownsville, LLC was incorporated in Delaware, United States, and has the corporate power to own and operate certain facilities for the storage and treatment of clean petroleum products. This investment is recorded under the equity method.

• Texas Frontera, LLC. This company was constituted on July 27, 2010, and its principal activity is the lease of tanks for the storage of refined product. PMI SUS, which owns 50% interest in Texas Frontera, entered into a joint venture with Magellan OLP, L.P. (Magellan), and together they are entitled to the results in proportion of their respective investment. As of December 31, 2016, the company has seven tanks with a capacity of 120,000 barrels per tank. This joint venture is recorded under the equity method.

F-59

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

• CH4 Energía, S.A. This company was constituted on December 21, 2000. CH4 Energía engages in the purchase and sale of natural gas and in activities related to the trading of natural gas, such as transport and distribution in Valle de Toluca, México. This joint venture is recorded under the equity method.

• Administración Portuaria Integral de Dos Bocas, S.A. de C.V. This company was constituted on August 12, 1999. Its primary activity is adminitrating the Dos Bocas port, which is in Mexico’s public domain, promoting the port’s infrastructure and providing related port services. This investment is recorded under the equity method.

• PMV Minera, S.A. de C.V. This company was constituted on October 1, 2014 and the principal activity is the extraction and sale of salmuera (mixture of salt and water). This investment is recorded under the equity method.

• Gasoductos de Chihuahua, S. de R.L. de C.V. On February 6, 1997, Pemex Industrial Transformation (formerly Pemex-Refining) entered into a joint venture with IEnova Gasoductos Holding, S. de R.L de C.V. to own and operate companies related to gas transportation and distribution, called Gasoductos de Chihuahua, S. de R.L. de C.V. Decision-making requires the consent of both partners. The participation of each of the partners was 50% of the share capital. This investment was recorded under the equity method until August 2016, when PEMEX completed the divestiture of this company as described in footnote (ii) to the table above.

• Compañía Mexicana de Exploraciones S.A. de C.V., (“COMESA”). COMESA was founded on November 12, 1968 to support PEMEX’s exploration programs. The operations of COMESA are focused on designing integral solutions for the energy sector, along the value chain for exploration and production, refining, petrochemicals, geothermal energy and other energy areas all over the energy sector in Mexico, South America and the United States. COMESA’s principal activities are: gravimetric, magnetometric and microseismic studies, land seismic data acquisition (2D,3D, 3C), marine Seismic data acquisition, seismic data processing, seismic data interpretation and integration, vertical Seismic Profile (VSP) 2D and 3D, reservoir characterization and visualization, conceptualization and definition for the exploration process. Until June 30, 2016 this company was accounted under the equity method. As of July 1, 2016 this company is included in the consolidated results.

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

NOTE 12. WELLS, PIPELINES, PROPERTIES, PLANT AND EQUIPMENT, NET

	Plants			Drilling equipment			Pipelines			Wells			Buildings			Offshore platforms			Furniture and equipment			Transportation equipment			Construction in progress			Land			Unproductive fixed assets			Other fixed assets			Total fixed assets
Investment
Balances as of January 1, 2016		Ps. 648,412,014			21,680,343			419,979,508			1,066,515,651			66,284,466			260,328,096			52,966,194			15,329,095			211,675,597			43,347,802			—			630,878			2,807,149,644
Acquisitions		20,406,464			1,629,710			1,265,011			8,239,480			2,541,802			9,866,984			545,271			2,063,519			107,682,868			1,487,434			6,800			—			155,735,343
Reclassifications		150,817			—			(1,268,887	)		8,649,686			(6,610,184	)		—			(561,569	)		(325,778	)		(282,044	)		50,709			2,039			(137,246	)		(332,457	)
Capitalization		15,943,630			—			11,851,378			40,825,973			1,085,323			17,318,279			2,769			2,918,621			(89,945,973	)		—			—			—			—
Impairment		81,135,967			—			31,967,407			198,974,994			—			35,640,491			438,979			8,743			(16,852,238	)		—			—			—			331,314,343
Disposals		(7,602,782	)		(40,937	)		(3,648,989	)		(4,382,867	)		(558,374	)		(449,645	)		(2,644,957	)		(551,355	)		(4,864,062	)		(314,327	)		(8,839	)		(2,126	)		(25,069,260	)
Balances as of December 31, 2016		758,446,110			23,269,116			460,145,428			1,318,822,917			62,743,033			322,704,205			50,746,687			19,442,845			207,414,148			44,571,618			—			491,506			3,268,797,613
Acquisitions		10,018,030			418,283			7,054,793			14,937,882			802,300			7,811,374			1,183,679			284,445			51,410,469			58,563			—			—			93,979,818
Reclassifications		3,146,955			—			(53,349	)		—			98,245			(10,199,213	)		(96,899	)		(75,674	)		(812,943	)		(560	)		—			4,072,464			(3,920,974	)
Capitalization		43,033,864			—			21,357,074			36,564,811			1,265,246			8,677,765			30,879			3,746,395			(114,700,828	)		29,248			—			(4,454	)		—
Impairment		(48,020,616	)		—			2,226,771			(83,236,991	)		—			(15,564,190	)		—			—			(6,849,534	)		—			—			—			(151,444,560	)
Disposals		(10,598,983	)		(244,283	)		(8,862,541	)		(19,340,709	)		(208,353	)		—			(806,694	)		(226,375	)		(6,724,930	)		(112,170	)		—			(4,440,865	)		(51,565,902	)
Balances as of December 31, 2017		Ps. 756,025,360			23,443,116			481,868,176			1,267,747,910			64,700,471			313,429,941			51,057,652			23,171,636			129,736,382			44,546,699			—			118,651			3,155,845,995
Accumulated depreciation and amortization
Balances as of January 1, 2016		Ps.(321,283,906	)		(578,015	)		(139,331,407	)		(780,443,639	)		(37,712,087	)		(140,908,960	)		(36,513,479	)		(5,894,520	)		—			—			—			—			(1,462,666,013	)
Depreciation and amortization		(44,549,443	)		(2,364,560	)		(15,153,879	)		(70,090,038	)		(1,796,383	)		(12,252,810	)		(3,205,089	)		(1,027,289	)		—			—			—			—			(150,439,491	)
Reclassifications		(10,521	)		—			(166,632	)		(3,077	)		(108,718	)		—			166,914			454,492			—			—			—			—			332,458
Disposals		5,826,891			—			2,286,691			—			492,557			—			2,560,988			550,554			—			—			—			—			11,717,681
Balances as of December 31, 2016		(360,016,979	)		(2,942,575	)		(152,365,227	)		(850,536,754	)		(39,124,631	)		(153,161,770	)		(36,990,666	)		(5,916,763	)		—			—			—			—			(1,601,055,365	)
Depreciation and amortization		(45,709,123	)		(2,198,867	)		(15,095,115	)		(74,673,473	)		(1,906,164	)		(13,192,369	)		(2,890,563	)		(1,038,839	)		—			—			—			—			(156,704,513	)
Reclassifications		2,799,244			—			(72,841	)		—			(69,236	)		1,146,904			102,375			14,532			—			—			—			—			3,920,978
Disposals		8,902,711			127,458			7,573,769			16,810,591			59,022			—			805,916			222,764			—			—			—			—			34,502,231
Balances as of December 31, 2017		Ps.(394,024,147	)		(5,013,984	)		(159,959,414	)		(908,399,636	)		(41,041,009	)		(165,207,235	)		(38,972,938	)		(6,718,306	)		—			—			—			—			(1,719,336,669	)
Wells, pipelines, properties, plant and equipment—net as of December 31, 2016		Ps. 398,429,131			20,326,541			307,780,201			468,286,163			23,618,402			169,542,435			13,756,021			13,526,082			207,414,148			44,571,618			—			491,506			1,667,742,248
Wells, pipelines, properties, plant and equipment—net as of December 31, 2017		Ps. 362,001,214			18,429,132			321,908,762			359,348,274			23,659,462			148,222,706			12,084,714			16,453,330			129,736,382			44,546,699			—			118,651			1,436,509,326
Depreciation rates		3 to 5	%		5	%		2 to 7	%		—			3 to 7	%		4	%		3 to 10	%		4 to 20	%		—			—			—			—			—
Estimated useful lives		20 to 35			20			15 to 45			—			33 to 35			25			3 to 10			5 to 25			—			—			—			—			—

a. As of December 31, 2017, 2016 and 2015, the financing cost identified with fixed assets in the construction or installation stage, capitalized as part of the value of such fixed assets, was Ps. 3,060,963, Ps. 3,667,752 and Ps. 5,258,854, respectively.

b. The combined depreciation of fixed assets and amortization of wells for the fiscal years ended December 31, 2017, 2016 and 2015, recognized in operating costs and expenses, was Ps.156,704,513, Ps. 150,439,491 and Ps. 167,951,250, respectively, which includes costs related to plugging and abandonment of wells for the years ended December 31, 2017, 2016 and 2015 of Ps. 850,015, Ps. 1,698,312, and Ps. 1,401,870, respectively.

c. As of December 31, 2017 and 2016, provisions relating to future plugging of wells costs amounted to Ps. 68,797,600 and Ps. 64,967,710, respectively, and are presented in the “Provisions for plugging of wells” (see Note 18).

F-61

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

d. As of December 31, 2017 and 2016, acquisitions of property, plant and equipment include transfers from wells unassigned to a reserve for Ps. 16,440,645 and Ps. 16,393,773, respectively (see Note 13) and Ps. 4,652,314 from available-for-sale non-financial assets as of December 31, 2017 (see Note 9).

e. As of December 31, 2017 and 2016, PEMEX recognized a net impairment of Ps. 151,444,560 and a net reversal of impairment of Ps. 331,314,343, respectively, which is presented as a separate line item in the consolidated statement of comprehensive income as follows:

i. As of December 31, 2017, the net impairment was as follows:

	Impairment			Reversal of impairment		Net Impairment
Pemex Exploration and Production	Ps.	(129,350,315	)	Ps.	—	Ps.	(129,350,315	)
Pemex Industrial Transformation		(19,751,882	)		3,799,790		(15,952,092	)
AGRO		(4,206,653	)		—		(4,206,653	)
Pemex Fertilizers		(1,935,500	)		—		(1,935,500	)
Total	Ps.	(155,244,350	)	Ps.	3,799,790	Ps.	(151,444,560	)

Cash Generating Unit of Pemex Exploration and Production

Pemex Exploration and Production recognized an impairment in the amount of Ps. 129,350,315 as of December 31, 2017, arising from: (i) the deferral of the development investments in the first 5 years of the economic horizon in the proved reserves, which caused a decrease in production and consequently in income, as well as the re-categorization of part of the proved reserves as probable reserve, as a consequence of budget adjustments in the strategic investments in the Cantarell, Aceite terciario del Golfo, Crudo Ligero Marino, Antonio J. Bermúdez and Tzimin Xux projects, (ii) insufficient cash flows to make up for costs recovery at the Burgos and Lakach projects as a resulting from the appreciation of the Mexican peso against the U.S. dollar by 4.3%, from a peso—U.S. dollar exchange rate of Ps. 20.6640 to U.S. $1.00 as of December 31, 2016 to a peso—U.S. dollar exchange rate of Ps. 19.7867 to U.S. $1.00 as of December 31, 2017, given that cash inflows are denominated in U.S. dollars and then translated to the reporting currency using the exchange rate at the date of report; (iii) a 0.3% increase in the discount rate; (iv) a 7.2% decrease in crude oil forward prices from 60.24 usd/bl in 2016 to 55.89 usd/bl in 2017 and (v) the natural decline in production in the Macuspana project.

The cash generating units of Pemex Exploration and Production are investment projects in productive fields with hydrocarbon reserves associated with proved reserves (1P). These productive hydrocarbon fields contain varying degrees of heating power consisting of a set of wells and are supported by fixed assets associated directly with production, such as pipelines, production facilities, offshore platforms, specialized equipment and machinery.

Each project represents the smallest unit which can concentrate the core revenues, with clear costs and expenses that enable future cash flows (value in use) to be determined.

F-62

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

To determine the value in use of long-lived assets associated with hydrocarbon extraction, the net present value of reserves is determined based on the following assumptions:

Average crude oil price	55.89 U.S. dollars/bl
Average gas price	4.92 U.S. dollars /mpc
Average condensates price	38.33 U.S. dollars /bl
Discount rate	14.40% annually

The total forecast production, calculated with a horizon of 25 years is 7,091 million bpce.

Pemex Exploration and Production determines the recoverable amount of fixed assets based on the long-term estimated prices for Pemex Exploration and Production’s proved reserves (1P). The recoverable amount on each asset is the value in use.

Cash Generating Units of Pemex Industrial Transformation

As of December 31, 2017, Pemex Industrial Transformation recognized a net impairment of Ps. (15,952,092).

The impairment was in the following cash generating units:

Minatitlán Refinery	Ps.	(5,691,005	)
Madero Refinery		(8,480,880	)
Salina Cruz Refinery		(5,579,997	)
Total impairment of assets		(19,751,882	)
Cangrejera Petrochemical Center		3,565,355
Independencia Petrochemical Center		112,292
Arenque gas processor complex		57,039
Matapionche gas processor complex		65,104
Reversal of impairment		3,799,790
Net impairment	Ps.	(15,952,092	)

The impairment was mainly due to (i) an increase in capitalizable maintenance expenses in refining; (ii) the appreciation of the Mexican peso against the U.S. dollar, from a peso—U.S. dollar exchange rate of Ps. 20.6640 to U.S. $1.00 as of December 31, 2016 to a peso—U.S. dollar exchange rate of Ps. 19.7867 to U.S. $1.00 as of December 31, 2017; partially offset by (i) an increase in the transportation fees; (ii) an increase in the processing of wet gas due to higher imports of this product and redistribution by Pemex Exploration and Production; (iii) an increase in prices arising from the price liberalization in 2017; and (iv) a decrease in the discount rate of cash generating units of refined products, gas and petrochemicals of 4.4%, 4.5%, and 5.6%, respectively.

Cash-generating units in Pemex Industrial Transformation are processing centers grouped according to their types of processes as refineries, gas complex processors, and petrochemical centers. These centers produce various finished products for direct sale to customers or intermediate products that can be processed in another of its cash generating units or by a third party. Each processing center of Pemex Industrial Transformation

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

represents the smallest unit which can concentrate the core revenues, with clear costs and expenses that enable future cash flows (value in use) to be determined.

Cash flow determinations are made based on PEMEX’s business plans, operating financial programs, forecasts of future prices of products related to the processes of the cash generating units, budget programs and various statistical models that consider historical information of processes and the capacity of the various processing centers.

To determine the value in use of long-lived assets associated with the cash-generating units of Pemex Industrial Transformation, the net present value of cash flows was determined based on the following assumptions:

	Refining	Gas	Petrochemicals
Average crude oil Price	51.30 U.S. dollars	N.A.	N.A.
Processed volume	767 mbd	3,085 mmpcd or sour gas	Variable because the load inputs are diverse
Rate of U.S. dollar	Ps.19.7867 mxp/usd	Ps.19.7867 mxp/usd	Ps.19.7867 mxp/usd
Useful lives of the cash generating units	Average of 16 years	Average of 9 years	Average of 6 years
Discount rate	11.53% annually	10.24% annually	9.71% annually
Period	2018-2034	2018-2029	2016-2024

The recoverable amount of assets is based on each asset’s value in use. The value in use for each asset is calculated based on cash flows, taking into consideration the volumes to be produced and sales to be carried out. As of December 31, 2017, the value in use for the impairment or reversal of impairment of fixed assets was as follows:

Minatitlán Refinery	Ps. 32,531,925
Madero Refinery	11,420,952
Salina Cruz Refinery	12,051,597
Cangrejera Petrochemical Center	17,544,825
Independencia Petrochemical Center	3,146,413
Arenque gas processor complex	1,283,201
Matapionche gas processor complex	1,074,729
Total value in use	Ps. 79,053,642

Pro-Agroindustria, S.A. de C.V.

Pro-Agroindustria, S.A. de C.V. recognized an impairment for Ps. (4,206,653) related to its nitric acid, amonium nitrate and UAN 32 acquired plants, the rehabilitation of which has not yet commenced. The company will not be able to develop an alternate plan for the rehabilitation of these plants in the following five years due to its financing commitments.

Cash Generating Units of Pemex Fertilizers

Cash generating units are plants used in the ammonia process.

F-64

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Pemex Fertilizers recognized an impairment of Ps. (1,935,500) for the year ended December 31, 2017 resulting from (i) a decrease in the production capacity in fertilizers plants due to a shortage of raw material; (ii) an increase in raw material prices; and (iii) a decrease in ammonia sale prices.

The recoverable amount of assets is based on each asset’s value in use. To determine cash flows, volumes to be produced and sales to be carried out were taken into consideration. The value in use for the impairment of fixed assets was Ps. 2,744,600. The discount rate used was 9.71%.

ii. As of December 31, 2016, the net reversal of impairment was as follows:

	Impairment			Reversal of impairment		Reversal of impairment
Pemex Exploration and Production		Ps. (16,872,238	)		Ps. 288,581,670		Ps. 271,709,432
Pemex Industrial Transformation		(2,768,267	)		55,267,148		52,498,881
Pemex Logistics		—			5,829,520		5,829,520
Pemex Ethylene		—			1,276,510		1,276,510
Total		Ps. (19,640,505	)		Ps. 350,954,848		Ps. 331,314,343

Cash Generating Unit of Pemex Exploration and Production

Pemex Exploration and Production recognized a net reversal of impairment in the amount of Ps. 271,709,432 as of December 31, 2016, arising from (1) a reversal of Ps. 288,581,670 mainly due to the reallocation of resources towards oil fields with highest profitability and net cash flows arising from relatively greater efficiency in oil extraction and lower production costs, which fields are located primarily in the Aceite Terciario del Golfo, Crudo Ligero Marino, Burgos, Cantarell and Antonio J. Bermudez crude oil projects, (ii) the appreciation of the U.S. dollar against the Mexican peso by 20.1%, from a peso—U.S. dollar exchange rate of Ps. 17.2065 to U.S. $1.00 as of December 31, 2015 to a peso—U.S. dollar exchange rate of Ps. 20.6640 to U.S. $1.00 as of December 31, 2016, given that cash inflows are denominated in U.S. dollars and then translated to the reporting currency using the exchange rate at the end of the period, (iii) the change in the period used to estimate long-term prices of proved reserves and the recoverable amount of fixed assets from 20 years to 25 years in accordance with the amendment to the Lineamientos que regulan el procedimiento de cuantificación y certificación de reservas de la nación y el informe de los recursos contingentes relacionados (Guidelines regulating the quantification and certification procedures of the nation’s reserves and the related contingent resources report), (iv) the authorization, with respect to the assignments that are to be safeguarded for two years, to consider such assignments for an undetermined time until they are bidded and assigned to a contract and (v) the decrease in the discount rate; (2) an impairment of fixed assets of Ps. (16,872,238), mainly due to the fact that cash flows were not sufficient to cover the recovery value of the Lakach project as a result of the increase in investments in this strategic gas project.

The cash generating units of Pemex Exploration and Production are investment projects in productive fields with hydrocarbon reserves associated with proved reserves (1P). These productive hydrocarbon fields contain varying degrees of heating power consisting of a set of wells and are supported by fixed assets associated directly with production, such as pipelines, production facilities, offshore platforms, specialized equipment and machinery.

F-65

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Each project represents the smallest unit which can concentrate the core revenues, with clear costs and expenses that enable future cash flows (value in use) to be determined.

To determine the value in use of long-lived assets associated to hydrocarbon extraction, the net present value of reserves is determined based on the following assumptions:

Average crude oil price	60.24 U.S. dollars/bl
Average gas price	4.69 U.S. dollars/mpc
Average condensates price	40.22 U.S. dollars/bl
Discount rate	14.36% annually

The total forecast production, calculated with a horizon of 25 years is 7,092 million bpce.

Pemex Exploration and Production determines the recoverable amount of fixed assets based on the long-term estimated prices for Pemex Exploration and Production’s proved reserves (1P). The recoverable amount on each asset is the value in use.

Cash Generating Unit of Pemex Industrial Transformation

As of December 31, 2016, Pemex Industrial Transformation recognized a net reversal of impairment of Ps. 52,498,881.

The net reversal of impairment was in the following cash generating units:

Minatitlán Refinery	Ps. 33,165,095
Madero Refinery	21,833,892
Arenque gas processor complex	268,161
Reversal of impairment	55,267,148
Cangrejera Petrochemical Center	(2,590,870	)
Independencia Petrochemical Center	(112,292	)
Matapionche gas processor complex	(65,105	)
Total impairment of assets	(2,768,267	)
Net reversal of impairment	Ps. 52,498,881

As of December 31, 2016, Pemex Industrial Transformation recognized a net reversal of impairment of Ps. 52,498,881 mainly due to (1) a reversal of impairment of Ps. 55,267,148 corresponding to the Madero and Minatitlán refineries due to higher prices than were forecasted in 2015 during the market decline, a decrease in the discount rate in the National Refinery System from 13.72% to 12.06%, and the appreciation of the U.S. dollar against the Mexican peso by 20.1%, from a peso—U.S. dollar exchange rate of Ps. 17.2065 to U.S. $1.00 as of December 31, 2015 to a peso—U.S. dollar exchange rate of Ps. 20.6640 to U.S. $1.00 as of December 31, 2016; (2) a reversal of impairment of the cash generating units of the Arenque gas processor complex of Ps. 268,161 due to an increase in the prices, the appreciation of the U.S. dollar against the Mexican peso and, improved efficiency in operating expenses and (3) impairment of three additional cash generating units, including Ps. (65,105) in the Matapionche gas processor complex, Ps. (2,590,870) in the Cangrejera Petrochemical Center and Ps. (112,292) for the Independencia Petrochemical Center, due to a decrease in the methanol price produced in these petrochemical centers.

F-66

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Cash-generating units in Pemex Industrial Transformation are processing centers grouped according to their types of processes as refineries, gas complex processors, and petrochemical centers. These centers produce various finished products for direct sale to or intermediate products that can be processed in another of its cash generating units or by a third party.

Each processing center of Industrial Transformation represents the smallest unit which can concentrate the core revenues, with clear costs and expenses that enable future cash flows (value in use) to be determined.

Cash flows determination is made based on PEMEX’s business plans, operating financial programs, forecasts of future prices of products related to the processes of the cash generating units, budget programs and various statistical models that consider historical information of processes and the capacity of the various processing centers.

To determine the value in use of long-lived assets associated with the cash-generating units of Pemex Industrial Transformation, the net present value of cash flows was determined based on the following assumptions:

	Refining	Gas	Petrochemicals
Average crude oil price	52.30 U.S. dollars	N.A.	N.A.
Processed volume	1,100 mbd	3,085 mmpcd or sour gas	Variable because the load inputs are diverse
Rate of U.S. dollar	Ps.20.6640 mxp/usd	Ps.20.6640 mxp/usd	Ps.20.6640 mxp/usd
Useful lives of the cash generating units	Average of 14 years	Average of 10 years	Average of 4 years
Discount rate	12.06% annually	10.72% annually	10.29% annually
Period	2018-2034	2018-2029	2016-2024

The recoverable amount of assets is based on each asset’s value in use. The value in use for each asset is calculated based on cash flows, taking into consideration the volumes to be produced and sales to be carried out. As of December 31, 2017, the value in use for the impairment or reversal of impairment of fixed assets was as follows:

Minatitlán Refinery	Ps. 43,856,284
Madero Refinery	33,961,120
Salina Cruz Refinery	36,057,410
Cangrejera Petrochemical Center	2,441,686
Independencia Petrochemical Center	1,706,687
Arenque gas processor complex	473,499
Matapionche gas processor complex	572,909
Total value in use	Ps. 119,069,595

Cash generating unit of logistics

The cash generating units of PEMEX’s logistics segments are pipelines, tankers, storage terminals and transportation equipment used for service, transport and storage of oil, oil products and petrochemicals.

F-67

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Pemex Logistics calculates the recoverable amount of assets based on the value in use. The value in use for each asset is calculated based on cash flows, taking into consideration services income. As of December 31, 2016, the value in use amounted to Ps. 139,436,715. Until December 31, 2016, the projection of cash flows was calculated based on a period of 5 years. During 2016 the discount rate used was 12.63%.

As of December 31, 2016, reversal of impairment amounted Ps. 5,829,520, mainly due to improvements in operating costs.

Cash generating unit of ethylene

Pemex Ethylene calculates the recoverable amount of assets based on the value in use. The value in use for each asset is calculated based on cash flows, taking into consideration services income. As of December 31, 2016 reversal of impairment amounted to Ps.1,276,510. During 2016 the discount rate used was 10.29%.

f. PEMEX entered into certain capital lease arrangements for tankers. These leases expire on various dates until 2018.

As of December 31, 2013, PEMEX had entered into nine capital lease arrangements for drilling equipment. These leases expire on various dates over the next 10 years.

As of December 31, 2015, PEMEX had entered into certain capital lease arrangements for two offshore platforms. These leases expire on various dates over the next 10 years.

As of December 31, 2017 and 2016, assets acquired through these capital leases were as follows:

	2017			2016
Investment in tankers and drilling equipment	Ps.	11,142,197		Ps.	11,142,197
Less accumulated depreciation		(1,696,089	)		(1,274,314	)
	Ps.	9,446,108		Ps.	9,867,883

The liabilities relating to the assets listed above are payable in the years following December 31, 2017 as presented below:

Year	Pesos		U.S. dollars
2018		Ps. 1,867,411		94,377
2019		1,192,496		60,268
2020		1,192,496		60,268
2021		1,192,496		60,268
2022		1,192,496		60,268
2023 and thereafter		2,158,559		109,091
		8,795,954		444,540
Less: short-term unaccrued interest		331,412		16,749
Less: long-term unaccrued interest		843,480		42,630
Total capital leases		7,621,062		385,161
Less: current portion of leases (excluding interest)		1,543,881		78,026
Total long-term capital leases		Ps. 6,077,181	U.S. $	307,135

F-68

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The interest expense from capital leases for the years ended December 31, 2017, 2016 and 2015 was Ps. 418,883, Ps. 500,654 and Ps. 450,760, respectively.

The discount rates applied to the calculation of capital leases were as follows:

i. 7.96 % rate in nominal terms (1.11% in real terms) as of December 31, 2017.

ii. 7.96 % rate in nominal terms (4.45% in real terms) as of December 31, 2016.

iii. 7.96 % rate in nominal terms (5.71% in real terms) as of December 31, 2015.

g. Certain infrastructure assets used for oil and gas activities are guarantees for the U.S. $1,100,000 and U.S. $600,000 sale and lease back agreements dated as of June 17, 2016 and July 8, 2016 (see Note 15).

h. PEMEX can conduct exploration and extraction activities through Exploration and Extraction Contracts (EEC). The EECs are awarded individually, through associations or joint ventures based on guidelines approved by the NHC and are classified into:

a. Production-sharing contracts;

b. Profit-sharing contracts;

c. License agreements; and

d. Service contracts.

Certain of the EECs are operated though joint arrangements, for which PEMEX recognizes in its financial statements, both the rights to the assets and the obligations for the liabilities, as well as profits and losses relating to the arrangements.

EECs as of December 31, 2017 are:

a. Production-sharing contracts

i. Hydrocarbon Extraction Contract (Shallow Water), Ek-Balam contractual area.

The object of the contract is the execution of oil activities, under shared production contracts, between, Mexico through the Mexican Government via the NHC and Pemex Exploration and Production, as a contractor, for the contractual area and all the costs, risks, terms and conditions involved in the contract and in accordance with the applicable regulations and best practices of the Industry receiving, in exchange, benefits in favor of the contractor.

Pemex Exploration and Production got the 100% of this contractual area.

ii. Exploration and Extraction Contract related to Area 2 Tampico Misantla, with the association formed by Pemex Exploration and Production and DEA.

The object of the contract is the realization of oil activities, under shared production contracts, by the contractor for the contractual area and all the costs, risks, terms and conditions involved in the contract and in accordance with the applicable regulations and best practices of the Industry receiving, in exchange, benefits in favor of the contractor.

Pemex Exploration and Production owns 70% of this contractual area, while DEA has the 30% of this contractual area, respectively. The condition of operator will be in charge of Pemex Exploration and Production.

F-69

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

This contract requires a total investment of U.S. $ 45,230 million, of which U.S. $ 36,520 million correspond to exploratory activities to be carried out in the period of 2017-2021.

iii. Exploration and Extraction Contract, related to Area 8 Cuencas del Sureste, pursuant to consortium formed by Pemex Exploration and Production and EPC Hidrocarburos México, S. A. de C. V. company (EPC).

Pemex Exploration and Production was designated by all the participating companies and with the approval of the NHC as the operator of this contract and all operational aspects of the petroleum activities will be carried out only by the operator on behalf of all participating companies.

Pemex Exploration and Production and EPC each have a 50% interest in this contractual area.

b. License contracts

i. A licensing contract with BHP Billiton Petróleo Operaciones de México, S. de R.L. (BHP Billiton) for the Trión block, under which BHP Billiton has the right to explore and extract hydrocarbons owned by Mexico in the contractual area and bears the costs and risks associated with such exploration and extraction activities.

BHP Billiton owns 60% of the contractual area, while Pemex Exploration and Production owns 40%.

ii. Hydrocarbons Exploration and Extraction Contract for the contractual area 3 “Plegado Perdido”, in deep waters, formed by Inpex, Chevron and Pemex Exploration and Production.

A licensing contract that permits the exploration and extraction of hydrocarbons owned by Mexico in the contractual area. Chevron was appointed by the participating companies, with the approval of the NHC, as the operator of this contract on behalf of each of the participating companies.

Chevron, Pemex Exploration and Production and Inpex have a 33.3334%, 33.3333% and 33.3333% interest in this project, respectively.

F-70

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

See below for a condensed statement of comprehensive income and condensed statement of financial position, summarizing the projects listed above:

	Profit-sharing								License
As of /For the year ended December 31, 2017	EK / Balam		Block 2			Block 8			Trion		Block 3			Total
Sales:
Net sales	Ps.	7,009,464	Ps.	—		Ps.	—		Ps.	—	Ps.	—		Ps.	7,009,464
Cost of sales		5,447,955		5,953			4,845			—		511			5,459,264
Gross income (loss)		1,561,509		(5,953	)		(4,845	)		—		(511	)		1,550,200
Other income (loss), net		4,852		—			—			—		—			4,852
Administrative expenses		34,338		—			—			—		—			34,338
Operating income (loss)		1,532,023		(5,953	)		(4,845	)		—		(511	)		1,520,714
Taxes, duties and other		158,347		—			—			—		—			158,347
Net income (loss)	Ps.	1,373,676	Ps.	(5,953	)	Ps.	(4,845	)	Ps.	—	Ps.	(511	)	Ps.	1,362,367
Cash and cash equivalents	Ps.	—	Ps.	20		Ps.	25		Ps.	—	Ps.	—		Ps.	45
Accounts receivable		—		1,013			1,804			—		327			3,144
Total current assets		—		1,033			1,829			—		327			3,189
Wells, pipelines, properties, plant and equipment, net		14,869,906		—			—			4,498,234		1,107,311			20,475,451
Total assets		14,869,906		1,033			1,829			4,498,234		1,107,638			20,478,640
Suppliers		796,300		—			—			—		—			796,300
Taxes and duties payable		973		—			—			—		—			973
Other current liabilities		4,391		1,809			2,369			—		—			8,569
Total current liabilities		801,664		1,809			2,369			—		—			805,842
Total liabilities	Ps.	801,664	Ps.	1,809		Ps.	2,369		Ps.	—	Ps.	—		Ps.	805,842
Equity (deficit), net	Ps.	14,068,242	Ps.	(776	)	Ps.	(540	)	Ps.	4,498,234	Ps.	1,107,638		Ps.	19,672,798

NOTE 13. INTANGIBLE ASSETS

At December 31, 2017 and 2016, intangible assets are wells unassigned to a reserve, which amounted Ps. 9,088,563 and Ps. 8,639,242, respectively as follows:

	2017			2016
Wells unassigned to a reserve:
Balance at the beginning of period	Ps.	8,639,242		Ps.	14,304,961
Additions to construction in progress		20,553,952			20,526,300
Transfers against expenses		(3,663,986	)		(9,798,246	)
Transfers against fixed assets		(16,440,645	)		(16,393,773	)
Balance at the end of period	Ps.	9,088,563		Ps.	8,639,242

F-71

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

In addition, as of December 31, 2017 and 2016, PEMEX recognized expenses related to unsuccessful wells of Ps. 2,500,638 and Ps. 19,307,838, respectively, directly in its statement of comprehensive income.

NOTE 14. LONG-TERM NOTES RECEIVABLE AND OTHER ASSETS

a. Long-term notes receivable

As of December 31, 2017 and 2016, the balance of long-term notes receivable was as follows:

	2017		2016
Promissory notes issued by the Mexican Government	Ps	. 147,274,076	Ps	.140,578,871
Other long-term notes receivable(1)		1,218,833		8,028,731
Total long-term notes receivable	Ps	. 148,492,909	Ps	.148,607,602

(1) For 2016, primarily CENAGAS.

Promissory notes issued by the Mexican Government

	2017		2016
Total promissory notes	Ps	.149,796,282	Ps	.142,124,620
Less: current portion of notes receivable(1)		2,522,206		1,545,749
Long-term promissory notes	Ps	.147,274,076	Ps	.140,578,871

(1) The current portion of the promissory notes and the total yield payments are allocated under sundry debtors in accounts receivable, net (see Note 7).

On December 24, 2015, the SHCP published in the Official Gazette of the Federation the Disposiciones de carácter general relativas a la asunción por parte del Gobierno Federal de obligaciones de pago de pensiones y jubilaciones a cargo de Petróleos Mexicanos y sus empresas productivas subsidiarias (General provisions regarding the assumption by the Mexican Government of the payment obligations related to pensions and retirement plans of Petróleos Mexicanos and its productive state-owned subsidiaries). These regulations stated the terms, conditions, financing mechanisms and payment arrangements pursuant to which the SHCP would assume a portion of the payment obligations related to PEMEX’s pensions and retirement plans. An independent expert reviewed the calculation, the methodology used, the maturity profile and all of the information provided by PEMEX.

In accordance with these provisions and prior to the completion of the independent expert’s review described above, on December 24, 2015, the Mexican Government issued in advance payment, through the SHCP, a Ps. 50,000,000 non-negotiable promissory note due December 31, 2050 payable to Petróleos Mexicanos. The promissory note, which accrued interest at a rate of 6.93% per year, was recognized as a long-term note receivable in non-current assets once the independent expert named by SHCP concluded its review.

On August 5, 2016, Petróleos Mexicanos received promissory notes issued by the Mexican Government at a value of Ps. 184,230,586 as of June 29, 2016, as part of the Mexican Government’s assumption of a portion of the payment liabilities related to Petróleos Mexicanos and Subsidiary Entities’ pensions and retirement

F-72

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

plans, which notes were delivered in exchange for the Ps. 50,000,000 promissory notes issued to Petróleos Mexicanos on December 24, 2015. On August 15, 2016, Petróleos Mexicanos exchanged Ps. 47,000,000 of these promissory notes for short-term floating rate Mexican Government debt securities, known as Bonos de Desarrollo del Gobierno Federal (Development Bonds of the Mexican Government or “BONDES D”). Petróleos Mexicanos then sold the BONDES D to Mexican development banks at market prices.

Petróleos Mexicanos recognized a Ps. 135,439,612 increase in equity as a result of the Ps. 184, 230,586 of the promissory notes as of June 29, 2016, minus the Ps. 50,000,000 promissory note received by Petróleos Mexicanos on December 24, 2015, plus a Ps. 1,209,026 increase in the value of the promissory notes from June 29, 2016 to August 15, 2016, the date on which PEMEX received the promissory notes (see Note 21).

As of December 31, 2017 and 2016, these promissory notes amounted to Ps. 147,274,076 and Ps. 140,578,871, respectively. PEMEX intends is to hold them to maturity. These promissory notes will be converted into cash with annual maturity dates ranging from 2018 to 2042 and annual rates ranging from 4.65% to 7.03% with annual maturity dates in 2017 and ranging from 2017 to 2042 and annual rates ranging from 4.35% to 7.04% in 2016, as follows:

As of December 31, 2017
Number of Promissory Notes	Maturity	Yield Rate Range	Principal Amount
1	2018	4.65%	Ps.	2,522,206
1	2019	5.14%		3,580,302
1	2020	5.39%		4,421,320
1	2021	5.57%		5,238,081
1	2022	5.74%		5,804,485
5	2023 to 2027	5.87% to 6.32%		34,196,434
5	2028 to 2032	6.47% to 6.81%		35,338,617
5	2033 to 2037	6.85% to 7.03%		32,789,697
5	2038 to 2042	7.02% to 6.94%		25,905,140
	Total promissory notes			149,796,282
	Less: current portion		Ps.	2,522,206
	Long-term notes receivable		Ps.	147,274,076

F-73

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

As of December 31, 2016
Number of Promissory Notes	Maturity	Yield Rate Range	Principal Amount
1	2017	4.35%	Ps.	1,545,749
1	2018	4.65%		2,408,634
1	2019	5.14%		3,402,849
1	2020	5.39%		4,192,132
1	2021	5.57%		4,957,840
5	2022 to 2026	4.74% a 6.11%		30,986,252
5	2027 to 2031	6.32% a 6.77%		33,280,216
5	2032 to 2036	6.81% a 7.00%		31,370,504
6	2037 to 2042	6.94% a 7.04%		29,980,444
	Total promissory notes		Ps.	142,124,620
	Less: current portion			1,545,749
	Long-term notes receivable		Ps.	140,578,871

During 2017 and 2016, PEMEX received Ps. 9,233,950 and Ps. 3,597,654, respectively, in accrued yields from these promissory notes, which was recognized as financing income in the consolidated statement of comprehensive income.

Yield rates for these promissory notes are pre-determined and fixed all throughout their lifespans and up to their maturities. Accordingly, fixed rates may not reflect market interest rate conditions as of the due date of each promissory note. In addition, PEMEX believes the promissory notes do not have a credit risk because they are issued by the Mexican Government in Mexican pesos.

As of December 31, 2017, the remaining Ps. 22,217,300 corresponding to Ps. 47,000,000 of the Mexican Government contribution was transferred to the Fondo Laboral PEMEX (Pemex Labour Trust or “FOLAPE”), for the period from January 2017 to June 2017 in accordance with the authorized expenditure budget framework for the fiscal year 2017.

In addition, the promissory note maturing in 2017 was contributed to the FOLAPE in June 2017 in the amount of Ps. 1,562,288.

b. Other assets

At December 31, 2017 and 2016, the balance of other assets was as follows:

	2017		2016
Payments in advance	Ps.	4,683,117	Ps.	2,558,767
License		2,162,151		1,813,605
Rights-of-way		1,967,304		1,940,157
Other		2,672,605		3,200,116
Total other assets	Ps.	11,485,177	Ps.	9,512,645

F-74

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

NOTE 15. DEBT

The Federal Income Law applicable to PEMEX as of January 1, 2017, published in the Official Gazette of the Federation on November 17, 2016, authorized Petróleos Mexicanos and its Subsidiary Entities to incur an internal net debt up to Ps. 28,000,000 and an external net debt up to U.S. $7,100,000. PEMEX can incur additional internal or external debt, as long as the total amount of net debt (Ps. 150,000,000 equivalent to U.S. $8,055,900) does not exceed the ceiling established by the Federal Income Law.

On July 8, 2016, the Board of Directors of Petróleos Mexicanos approved policies and general requirements for obligations that constitute public debt of Petróleos Mexicanos and Subsidiary Entities, in accordance with Article 106 section I of the Petroleos Mexicanos Law.

Subsequently, the Board of Directors of PEMEX, approved the debt program for fiscal year 2017 in accordance with Article 13 section XXVI of the Petróleos Mexicanos Law.

During the period from January 1 to December 31, 2017, PEMEX participated in the following financing activities:

a. On February 14, 2017, Petróleos Mexicanos issued € 4,250,000 of debt securities under its Medium-Term Notes Program, Series C in three tranches: (i) € 1,750,000 of its 2.50% Notes due August 2021;(ii) € 1,250,000 of its 3.75% Notes due February 2024; and (iii) € 1,250,000 of its 4.875% Notes due February 2028.

b. On April 6, 2017, Petróleos Mexicanos executed a U.S. $132,000, non-revolving bilateral credit line from Banco Mercantil del Norte, S.A., Institución de Banca Múltiple, Grupo Financiero Banorte, due on April 6, 2024, which bears a fixed interest rate of 5.25%.

c. On May 15, 2017, Petróleos Mexicanos entered into a simple credit line in the amount of U.S. $400,000 at a floating interest rate linked to LIBOR plus 165 basis points, due May 2020 and was used in two tranches of U.S. $200,000 (on May 24, 2017 and July 14, 2017, respectively).

d. On June 16, 2017, Petróleos Mexicanos increased its Medium-Term Notes Program, Series C, from U.S. $72,000,000 to U.S. $92,000,000.

e. On July 17, 2017, Petróleos Mexicanos entered into a revolving credit facility in the amount of U.S. $1,950,000 and matures in 2020.

f. On July 18, 2017, Petróleos Mexicanos issued under its U.S.$92,000,000 Medium-Term Notes Program, Series C: (i) U.S. $2,500,000 of its 6.500% Notes due 2027; and (ii) U.S. $2,500,000 of its 6.75% Bonds due 2047.

g. On July 21, 2017, Petróleos Mexicanos consummated a tender offer pursuant to which it purchased U.S. $922,485 aggregate principal amount of its outstanding 5.750% Notes due 2018, U.S. $644,374 aggregate principal amount of its outstanding 3.500% Notes due 2018 and U.S. $172,591 aggregate principal amount of its outstanding 3.125% Notes due 2019.

h. On November 16, 2017, Petróleos Mexicanos issued £ 450,000 at a rate interest of its 3.750% Notes due 2025 under its U.S.$92,000,000 Medium-Term Notes Program, Series C.

i. On December 15, 2017, AGRO refinanced a credit line for U.S. $390,000, prepaying U.S. $140,000 and entering into a new credit line for the outstanding U.S. $250,000, which bears interest at a floating rate linked to LIBOR plus 250 basis points on a quarterly basis and matures on June 29, 2018.

j. On December 18, 2017, Petróleos Mexicanos entered into a bilateral credit line facility in the amount of U.S. $200,000, which bears interest at a floating rate linked to LIBOR plus 165 basis points and matures on December 18, 2020.

F-75

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

k. On December 21, 2017, Petróleos Mexicanos borrowed U.S. $300,000 from a bilateral credit line which bears interest at a floating rate linked to LIBOR plus 175 basis points, which matures on December 21, 2022.

All the financing activities were guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

From January 1 to December 31, 2017, PMI HBV obtained U.S. $15,141,500 in financing from its revolving credit line and repaid U.S. $14,914,000. As of December 31, 2017, the outstanding amount under this revolving credit line was U.S. $227,500.

As of December 31, 2017, Petróleos Mexicanos had U.S. $6,700,000 and Ps. 23,500,000 in available credit lines in order to ensure liquidity. The available amounts are U.S. $5,400,000 and Ps. 23,500,000, respectively.

The Federal Income Law that was applicable to PEMEX as of January 1, 2016, published in the Official Gazette of the Federation on November 18, 2015, authorized Petróleos Mexicanos and its Subsidiary Entities to incur an internal net debt up to Ps. 110,500,000 and an external net debt up to U.S. $8,500,000. PEMEX was entitled to incur additional internal or external debt, as long as the total amount of net debt (Ps.240,550,000 equivalent to U.S. $15,722,000) did not exceed the ceiling established by the Federal Income Law.

On November 18, 2014, the Board of Directors of Petróleos Mexicanos approved policies and general requirements for obligations that constitute public debt of Petróleos Mexicanos and Subsidiary Entities, in accordance with the Article 107 of the Petroleos Mexicanos Law.

Subsequently, the Board of Directors of PEMEX, approved the debt program for fiscal year 2016 in accordance with Article 13 section XXVI of the Petróleos Mexicanos Law.

During 2016, PEMEX participated in the following financing activities:

a. On January 25, 2016, Petróleos Mexicanos increased its Medium-Term Notes Program from U.S. $52,000,000 to U.S. $62,000,000.

b. On February 4, 2016, Petróleos Mexicanos issued U.S. $5,000,000 of debt securities under its Medium-Term Notes Program, Series C, in three tranches: (i) U.S. $750,000 of its 5.500% Notes due February 2019; (ii) U.S. $1,250,000 of its 6.375% Notes due February 2021; and (iii) U.S. $3,000,000 of its 6.875% Notes due August 2026. All debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

c. On February 5, 2016, Petróleos Mexicanos obtained a loan from a line of credit for Ps. 7,000,000,000 bearing interest at a floating rate linked to the TIIE, plus 0.55%, and matured on January 2017.

d. On March 15, 2016, Petróleos Mexicanos issued €2,250,000 of debt securities U.S. $62,000,000 Medium-Term Notes Program, Series C in two tranches: (i) €1,350,000 of its 3.750% Notes due to March 2019 and (ii) €900,000 of its 5.125% Notes due to March 2023. All debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

e. On March 17, 2016, Petróleos Mexicanos borrowed Ps. 2,000,000 from a credit line at a floating rate linked to TIIE and matured on March 2017.

F-76

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

f. On March 17, 2016, Petróleos Mexicanos borrowed Ps. 3,300,000 from a credit line at a floating rate linked to TIIE and matured on March 2017.

g. On March 23, 2016, Petróleos Mexicanos issued Ps. 5,000,000 of Certificados Bursátiles due to October 2019 at a floating rate linked to TIIE. As of December 31, 2016, all debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

h. On March 28, 2016, Petróleos Mexicanos borrowed Ps. 9,700,000 from a credit line at a floating rate linked to TIIE, and matured on March 2017.

i. On April 19, 2016, Petróleos Mexicanos borrowed €500,000 from a credit line at fixed rate of 5.11%, which matures on March 2023.

j. On May 31, 2016, Petróleos Mexicanos obtained a U.S. $300,000 bilateral credit line from Export Development Canada (EDC), due on May 2021, which bears interest at a floating rate linked to LIBOR.

k. On June 14, 2016, Petróleos Mexicanos issued CHF 375,000 of debt securities under its Medium-Term Notes Program, Series C, in two tranches: (1) CHF 225,000 of its 1.50% Notes due to June 2018 and (2) CHF 150,000 of its 2.35% Notes due to December 2021. The Notes are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

l. On June 17, 2016, Pemex Exploration and Production obtained approximately U.S. $1,100,000 in connection with the sale and leaseback of certain infrastructure assets used for oil and gas activities (see Note 12-g). As part of this transaction, Pemex Exploration and Production entered into a 15-year financial lease agreement, which will last for the greater part of the economic life of the asset, at a fixed rate of 8.38%, pursuant to which Pemex Exploration and Production will retain the operation of these assets and the title and ownership of such assets will revert to Pemex Exploration and Production at the end of this period following payment of an agreed price. This transaction was recognized as a financing activity due to the fact that PEMEX retained all of the risks and benefits associated with ownership of the asset and substantially all of the operating rights of the asset.

m. On July 8, 2016, Pemex Industrial Transformation obtained approximately U.S. $600,000 in connection with the sale and leaseback of a plant located in the Madero Refinery. As part of this transaction, Pemex Industrial Transformation entered into a 20-year financial lease agreement pursuant to which Pemex Industrial Transformation will retain the operation of the plant and title and ownership will revert to Pemex Industrial Transformation at the end of this period following payment of an agreed price. This transaction was recognized as a financing activity due to the fact that Pemex Industrial Transformation retained all of the risks and benefits associated with ownership of the asset and substantially all of the operating rights of the asset.

n. On July 26, 2016, Petróleos Mexicanos issued ¥80,000,000 Bonds at 0.54% due July 2026. The Bonds are guaranteed by the Japan Bank for International Cooperation.

o. On September 21, 2016, Petróleos Mexicanos issued U.S. $4,000,000 aggregate principal amount of debt securities under its U.S. $62,000,000 Medium-Term Notes Program, Series C, in two tranches: (i) U.S. $2,000,000 of its 4.625% Notes due to September 2023 and (ii) U.S. $2,000,000 of its 6.750% Bonds due to September 2047. The debt securities are guaranteed by Pemex Exploration and

F-77

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

p. On October 3, 2016, Petróleos Mexicanos consummated a tender and exchange offer pursuant to which it (i) purchased U.S. $687,725 aggregate principal amount of its outstanding 8.000% Notes due 2019 and U.S. $657,050 aggregate principal amount of its outstanding 5.750% Notes due 2018 and (ii) exchanged (a) U.S. $73,288 aggregate principal amount of its outstanding 5.750% Notes due 2018 for U.S. $69,302 aggregate principal amount of its 4.625% Notes due 2023 and U.S. $8,059 aggregate principal amount of its 6.750% Bonds due 2047 and (b) U.S. $1,591,961 aggregate principal amount of its outstanding 5.500% Bonds due 2044 for U.S. $1,491,941 aggregate principal amount of its 6.750% Bonds due 2047. The 4.625% Notes due 2023 and 6.750% Bonds due 2047 are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services and represent reopenings of the 4.625% Notes due 2023 and 6.750% Bonds due 2047, respectively, originally issued on September 21, 2016

q. On December 6, 2016, Petróleos Mexicanos increased its Medium-Term Notes Program, Series C, from U.S. $ 62,000,000 to U.S. $72,000,000.

r. On December 13, 2016, Petróleos Mexicanos issued U.S. $5,500,000 of its debt securities under its Medium-Term Notes Program, Series C in three tranches: (1) U.S. $3,000,000 at fixed rate of 6.50% due March 2027, (2) U.S. $1,500,000 a fixed rate of 5.375% due March 2022, and (3) U.S. $1,000,000 at a floating rate linked to LIBOR, due March 2022. As of December 31, 2016, all debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

s. On December 14, 2016, Petróleos Mexicanos entered into a term loan credit facility in the amount of U.S. $300,000 at floating rate linked to LIBOR, matures on December 2019.

Between January 1 and December 31, 2016, PMI HBV obtained and paid U.S. $11,369,800 in revolving credit lines. As of December 31, 2016 there was no outstanding amount.

As of December 31, 2016, Petróleos Mexicanos had U.S. $4,750,000 and Ps. 23,500,000 in available credit lines in order to ensure liquidity. The available amounts are U.S. $4,630,000 and Ps. 3,500,000, respectively.

Various financial transactions (including credit facilities and bond issuances) require compliance with various covenants that, among other things, place restrictions on the following types of transactions by PEMEX, subject to certain exceptions:

• The sale of substantial assets essential for the continued operations of its business.

• The incurrence of liens against its assets.

• Transfers, sales or assignments of rights to payment not yet earned under contracts for the sale of crude oil or natural gas, accounts receivable or other negotiable instruments.

As of December 31, 2017 and as of the date of the issuance of these consolidated financial statements, PEMEX was in compliance with the covenants described above.

F-78

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

As of December 31, 2017, long-term debt was as follows:

				Pesos		Foreign currency
	Rate of interest(1)	Maturity		(thousands)		(thousands)
U.S. dollars
Bonds	Fixed from 1.7% to 9.5% and LIBOR plus 0.35% to 3.65%		Various to 2047		Ps. 1,138,845,231	US$	57,556,097
Purchasing loans	LIBOR plus 0.85%		Various to 2018		25,722,710		1,300,000
Project financing	Fixed from 2.35% to 3.81% and LIBOR plus 0.24% to 1.75%		Various to 2025		64,974,389		3,283,741
Direct loans	Fixed from 5.25% to 5.44% and LIBOR plus 1.65%		Various to 2020		43,141,231		2,180,315
Syndicated loans	LIBOR plus 0.85%		Various to 2020		39,347,774		1,988,597
Bank loans	Fixed from 3.5% to 5.28%		Various to 2023		3,451,629		174,442
Financial leases	Fixed from 0.38% to 1.99%		Various to 2025		7,621,062		385,161
Lease-back (See Financing activities for 2016 l) and m))(4)	Fixed from 0.45% to 0.7%		Various to 2036		32,677,268		1,651,476
Total financing in U.S. dollars					1,355,781,294	US$	68,519,829
Euros
Bonds	Fixed from 1.875% to 5.5%		Various to 2030		287,386,195	€	12,097,975
Project financing	Fixed from 2.1% to 5.11%		Various to 2023		11,879,379		500,081
Total financing in Euros					299,265,574	€	12,598,056
Japanese yen:
Bonds	Fixed from 0.54% to 3.5% and LIBOR yen plus 0.75%		Various to 2026		30,541,407	¥	173,827,018
Pesos
Certificados bursátiles	Mexican Government Treasury Certificates (“Cetes”) , TIIE(1) less 0.06% to 1.35%, and fixed at 7.19% to 9.1%		Various to 2026		Ps. 149,564,918
Direct loans	Fixed at 6.55% and TIIE plus 0.85% to 1.25%		Various to 2025		28,597,423
Syndicated loans	TIIE plus 0.95		Various to 2025		33,646,107
Total financing in pesos					Ps. 211,808,448
Unidades de Inversión Certificados bursátiles
Certificados bursátiles	Zero rate and Fixed at 3.02% to 5.23%		Various to 2035		57,197,211
Other currencies:
Bonds	Fixed from 1.5% to 8.25%		Various to 2025		47,148,936
Total principal in pesos(2)					2,001,742,870
Plus: accrued interest					32,078,624
Notes payable to contractors(3)					4,053,577
Total principal and interest					2,037,875,071
Less: short-term maturities					122,957,558
Current portion of notes payable to contractors(3)					2,173,285
Accrued interest					32,078,624
Total short-term debt and current portion of long-term debt					157,209,467
Long-term debt (Note 16(c))					Ps. 1,880,665,604

F-79

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

As of December 31, 2016, long-term debt was as follows:

	Rate of interest(1)	Maturity	Pesos (thousands)		Foreign currency (thousands)
U.S. dollars
Bonds	Fixed from 3.125% to 9.5% and LIBOR plus 0.35% to 2.02%	Various to 2046		Ps. 1,131,389,914	U.S. $	54,751,738
Purchasing loans	LIBOR plus 0.8% to 0.85%	Various to 2016		2,479,680		120,000
Project financing	Fixed from 2.35% to 5.45% and LIBOR plus 0.01% to 1.71%	Various to 2021		84,711,684		4,099,481
Direct loans	Fixed at 5.44% and LIBOR plus 1.0%	Various to 2018		33,100,587		1,601,848
Syndicated loans	LIBOR plus 0.85%	Various to 2020		41,056,571		1,986,865
Bank loans	Fixed from 3.5% to 5.28%	Various to 2023		4,339,826		210,019
Financial leases	Fixed from 0.38% to 1.99%	Various to 2025		9,559,060		462,595
Lease-back (See Financing activities for 2016 l) and m))(4)	Fixed from 0.45% to 0.7%	Various to 2036		35,513,114		1,718,598
Total financing in U.S. dollars				1,342,150,436	U.S. $	64,951,144
Euros
Bonds	Fixed from 3.125% to 6.375%	Various to 2030		196,317,016	€	9,058,388
Project financing	Fixed at 2%	Various to 2016		10,836,200		500,000
Total financing in Euros				207,153,216	€	9,558,388
Japanese yen:
Bonds	Fixed at 3.5% and LIBOR yen plus 0.75%	Various to 2023		30,800,746	¥	173,809,300
Project financing	Fixed at 1.56% and Prime Rate yen plus 2.56%	Various to 2017		517,286		2,919,056
Total financing in yen				31,318,032	¥	176,728,356
Pesos
Certificados bursátiles	Mexican Government Treasury Certificates (“Cetes”) , TIIE(1) less 0.06% to 0.35%, and fixed at 7.19% to 9.15%	Various to 2026	Ps.	173,151,985
Direct loans	Fixed at 6.55% and TIIE plus 0.55% to 1.25%	Various to 2025		45,563,848
Syndicated loans	TIIE plus 0.95	Various to 2025		38,538,961
Revolved loans	TIIE plus 0.55	To 2016		20,000,000
Total financing in pesos			Ps.	277,254,794
Unidades de Inversión Certificados bursátiles
Certificados bursátiles	Zero rate and Fixed at 3.02% to 5.23%	Various to 2035		53,703,421
Other currencies:
Bonds	Fixed from 2.5% to 8.25%	Various to 2022		36,786,665
Total principal in pesos(2)				1,948,366,564
Plus: accrued interest				27,815,467
Notes payable to contractors(3)				6,988,699
Total principal and interest				1,983,170,730
Less: short-term maturities				144,169,619
Current portion of notes payable to contractors(3)				4,181,102
Accrued interest				27,815,467
Total short-term debt and current portion of long-term debt				176,166,188
Long-term debt (Note 16(c))			Ps.	1,807,004,542

F-80

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

(1) As of December 31, 2017 and 2016, interest rates were as follows: 3 month LIBOR of 1.69428% and 0.99789%, respectively; 6 month LIBOR of 1.83707% and 1.31767%, respectively; TIIE rate of 7.6241% and 6.1066%, respectively, for 28 days; TIIE rate of 7.6556% and 6.1875%, respectively, for 91 days; Cetes rate of 7.22% and 5.69%, respectively, for 28 days; Cetes rate of 7.36% and 5.96%, respectively, for 91 days; Cetes rate of 7.53% and 6.09%, respectively, for 182 days.

(2) Includes financing from foreign banks of Ps. 1,701,363,406 and Ps. 1,600,968,832, as of December 31, 2017 and 2016, respectively.

(3) The total amounts of notes payable to contractors as of December 31, 2017 and 2016, current and long-term, are as follows:

	2017		2016
Total notes payable to contractors(a)(b)		Ps.4,053,577		Ps.6,988,699
Less: current portion of notes payable to contractors		2,173,285		4,181,102
Notes payable to contractors (long-term)		Ps.1,880,292		Ps.2,807,597

(a) PEMEX has entered into FPWCs pursuant to which the hydrocarbons and construction in progress are property of Pemex Exploration and Production. Pursuant to the FPWC, the contractors manage the work in progress, classified as development, infrastructure and maintenance. As of December 31, 2017 and 2016, PEMEX had an outstanding amount payable of Ps. 1,678,843 and Ps. 3,986,565, respectively.

(b) During 2007, Pemex-Exploration and Production contracted for the purchase of a Floating Production Storage and Offloading (“FPSO”) vessel. The investment in the vessel totaled U.S. $723,575. As of December 31, 2017 and 2016, the outstanding balances owed to the contractor were Ps. 2,374,734 (U.S. $120,017) and Ps. 3,002,134 (U.S. $145,283), respectively. In accordance with the contract, the estimated future payments are as follows:

Year	Amount
2018	U.S.$	25,267
2019		25,267
2020		25,267
2021		25,267
2022		18,949
Total	U.S $	120,017

(4) PEMEX obtained financing through the sale and leaseback of certain infrastructure assets and a plant, which will require periodic payments through 2036.

This transaction was recognized as a financing activity due to the fact that PEMEX retained all of the risks and benefits associated with ownership of the asset and substantially all of the operating rights to the assets.

F-81

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The outstanding liability for this transaction is payable as follows:

Years	Pesos		U.S. dollars
2018		Ps. 3,957,317	U.S. $	199,999
2019		3,886,037		196,396
2020		3,886,037		196,396
2021		3,886,037		196,396
2022		3,886,037		196,396
2023 and thereafter		39,450,325		1,993,781
		58,951,790		2,979,364
Less: short-term unaccrued interest		2,399,475		121,267
Less: long-term unaccrued interest		23,875,047		1,206,621
Total financing		32,677,268		1,651,476
Less: short-term portion of financing (excluding interest)		1,557,842		78,732
Total long term financing		Ps. 31,119,426	U.S.$	1,572,744

(5) As of December 31, 2017 and 2016, PEMEX used the following exchange rates to translate the outstanding balances in foreign currencies to pesos in the statement of financial position:

	2017		2016
U.S. dollar		Ps. 19.7867		Ps. 20.6640
Japanese yen		0.1757		0.1772
Pounds sterling		26.7724		25.3051
Euro		23.7549		21.6724
Swiss francs		20.2992		20.1974
Canadian dollar		15.7858		15.2896
Australian dollar		15.4752		14.8842

2018

2019

2020

2021

2022

2023 and thereafter

Total

Maturity of the total principal outstanding and accrued interest as of December 31, 2017, for each of the years ending December 31.

Ps.157,209,467

Ps.159,403,397

Ps,209,915,748

Ps.185,307,669

Ps.158,761,145

Ps.1,167,277,645

Ps.2,037,875,071

F-82

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The following table presents the roll-forward of total debt of PEMEX for each of the year ended December 31, 2017 and 2016, which includes short and long-term debt:

	2017(i)			2016(i)
Changes in total debt:
At the beginning of the year		Ps.1,983,170,730			Ps.1,493,381,835
Cash flows:
Loans obtained—financing institutions		704,715,468			829,579,084
Loans obtained—financing lease		—			21,924,053
Debt payments		(642,059,819	)		(614,987,329	)
Interest paid		(108,910,417	)		(88,757,428	)
Non-cash flows:
Foreign exchange		(16,685,439	)		243,182,764
Accrued interest		117,644,548			98,847,751
At the end of the year		Ps.2,037,875,071			Ps.1,983,170,730

NOTE 16. DERIVATIVE FINANCIAL INSTRUMENTS

PEMEX faces market risk caused by the volatility of hydrocarbon prices, exchange rates and interest rates, credit risk associated with investments and financial derivatives, as well as liquidity risk. In order to monitor and manage these risks, PEMEX has approved general provisions relating to financial risk management, which are comprised of policies and guidelines that promote an integrated framework for risk management, regulate the use of derivative financial instruments (“DFIs”), and guide the development of risk mitigation strategies.

This regulatory framework establishes that DFIs should be used only for the purpose of mitigating financial risk. The use of DFIs for any other purpose must be approved in accordance with PEMEX’s current internal regulation.

Approved DFIs are mainly traded on the OTC (Over the Counter) market. However exchange traded instruments may also be used. In the case of PMI Trading, DFIs are traded on CME-ClearPort.

One of PEMEX’s policies is to contribute minimizing the impact that unfavorable changes in financial risk factors have on its financial results by promoting an adequate balance between expected incoming cash flows from operations and outgoing cash flows related to its liabilities.

As part of the regulatory framework for financial risk management, PEMEX has established in its internal procedures the eligible counterparties to trade DFIs and other financial instruments.

In addition, certain PMI subsidiaries have implemented a regulatory framework for risk management with respect to its activities, which consists of policies, guidelines and procedures to manage the market risk associated with its commodity trading activities in accordance with industry best practices, such as: 1) the use of DFIs for financial risk mitigation purposes; 2) the segregation of duties; 3) valuation and monitoring mechanisms, such as the generation of a daily portfolio risk report, value at risk (VaR) computation; and 4) VaR limits, both at a global and business unit level and the implementation of stop loss mechanisms. In addition, PMI Trading also has its own risk management subcommittee that supervises the trading of DFIs.

F-83

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Given that PEMEX’s outstanding DFIs have been entered into for risk mitigation purposes, particularly with economic hedging purposes, it is unnecessary to establish and monitor market risk limits.

For those portfolios with an open market risk exposure, PEMEX’s financial risk management regulatory framework establishes the implementation and monitoring of market risk limits such as VaR and capital at risk (an aggregation of fair value or mark-to-market (“MtM”) and profit and loss, or CaR).

PEMEX has also established credit guidelines for DFIs that Pemex Industrial Transformation offers to its domestic customers, which include the use of guarantees and credit lines. For exchange traded DFIs, PEMEX trades under the margin requirements of the corresponding exchange market, and therefore does not have internal policies for these DFIs.

DFIs held with financial counterparties do not include collateral exchange clauses. Notwithstanding, PEMEX’s regulatory framework promotes credit risk mitigation strategies such as collateral exchange

A. Risk Management

I. Market Risk

i. Interest rate risk

PEMEX is exposed to fluctuations in floating interest rate liabilities. PEMEX is exposed to U.S. dollar LIBOR and to Mexican peso TIIE. As of December 31, 2017, approximately 15.6% of PEMEX’s total net debt outstanding consisted of floating rate debt.

Occasionally, for strategic reasons or in order to offset the expected inflows and outflows, PEMEX has entered into interest rate swaps. Under its interest rate swap agreements, PEMEX acquires the obligation to make payments based on a fixed interest rate and is entitled to receive floating interest rate payments based on LIBOR, TIIE or a rate referenced to or calculated from TIIE.

As of December 31, 2017, PEMEX was a party to four interest rate swap agreements denominated in U.S. dollars for an aggregate notional amount of U.S. $1,623,750 at a weighted average fixed interest rate of 2.35% and a weighted average term of 7.3 years.

Similarly, in order to eliminate the volatility associated with variable interest rates of long-term financing operations, PMI NASA has executed interest rate swap agreements denominated in U.S. dollars for an aggregate notional amount of U.S. $71,936, at a weighted average fixed interest rate of 4.17% and a weighted average term of 4.41 years.

Moreover, PEMEX invests in pesos and U.S. dollars in compliance with applicable internal regulations, through portfolios that have different purposes that seek an adequate return subject to risk parameters that reduce the probability of capital losses. The objective of the investments made through these portfolios is to meet PEMEX’s obligations payable in pesos and U.S. dollars.

The investments made through PEMEX’s portfolios are exposed to domestic and international interest rate risk and credit spread risk derived from government and corporate securities, and inflation risk arising from the relationship between UDIs and pesos. However, these risks are mitigated by established limits on exposure to market risk.

F-84

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

ii. Exchange rate risk

Most of PEMEX’s revenues are denominated in U.S. dollars, a significant amount of which is derived from exports of crude oil and petroleum products, which are priced and payable in U.S. dollars. Additionally, PEMEX’s revenues from domestic sales of gasoline and diesel net of IEPS Tax, tax duties, incentives, and other related taxes, as well as domestic sales of natural gas and its byproducts, LPG and petrochemicals, are referenced to international U.S. dollar-denominated prices.

PEMEX’s expenses related to hydrocarbon duties are calculated based on international U.S. dollar-denominated prices and the cost of hydrocarbon imports that PEMEX acquires for resale in Mexico or use in its facilities are indexed to international U.S. dollar-denominated prices. By contrast, PEMEX’s capital expenditure and operating expenses are established in pesos.

As a result of this cash flow structure, the depreciation of the peso against the U.S. dollar increases PEMEX’s financial balance. The appreciation of the peso relative to the U.S. dollar has the opposite effect. PEMEX manages this risk without the need for hedging instruments, because the impact on PEMEX’s revenues of fluctuations in the exchange rate between the U.S. dollar and the peso is offset in whole or in part by its impact on its obligations.

Therefore, PEMEX prioritizes debt issuances denominated in U.S. dollars; nonetheless, this is not always achievable, hence non-U.S. dollar debt issued in international currencies are hedged through DFIs to mitigate their exchange rate exposure, either by swapping them into U.S. dollars or through other derivative structures. The rest of the debt is denominated in pesos or in UDIs, for which most of the debt denominated in UDIs has been converted into pesos through DFIs in order to eliminate the inflationary risk exposure.

As a consequence of the above, PEMEX’s debt issued in international currencies other than U.S. dollars has exchange rate risk mitigation strategies. PEMEX has selected strategies that further seek to reduce its cost of funding by leaving, in some cases, part of this exchange rate exposure unhedged when assessed appropriate.

The underlying currencies of PEMEX’s DFIs are the euro, Swiss franc, Japanese yen, Pound sterling and Australian dollar versus the U.S. dollar and UDIs versus the peso.

In 2017, PEMEX entered into various cross-currency swaps to hedge inflation risk arising from debt denominated in UDIs, for an aggregate notional amount of Ps. 6,291,969. During 2016, PEMEX entered into the same kind of instruments to hedge currency risk arising from debt obligations denominated in euros and Swiss francs for an aggregate notional amount of U.S. $3,459,236 and the inflation risk arising from debt denominated in UDIs, for an aggregate notional amount of Ps. 1,077,101.

Most of PEMEX’s cross-currency swaps are plain vanilla except for one swap entered into in 2004 to hedge its exposure to the euro, which expired in 2016. This swap was referred to as an “extinguishing swap” and was obtained in order to hedge long-term obligations. The main characteristic of extinguishing swaps was that these DFIs terminate upon the occurrence of any of the credit default events specified in the DFI contract confirmation, without any payment obligation for either party. This swap had a notional amount of U.S. $1,146,410.

In 2016, PEMEX entered into, without cost, an options structure called “Seagull Option” in order to cover the notional risk of a debt issue in Japanese yen for ¥80,000,000, keeping the coupons in the original currency

F-85

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

(0.5% annual coupon rate). This structure protects the short exposure in Japanese yen against an appreciation of the Japanese yen versus the U.S. dollar from JPY 83.70 and up to JPY 75.00 and recognizes a benefit if the Japanese yen depreciates to an average of 117.39 JPY/USD.

Moreover, in 2017 PEMEX entered into, without cost, three more Seagull Options to hedge the notional risk of three debt issues in euros for an aggregate notional amount of € 4,250,000. These structures protect the short exposure in euros against an appreciation of the euro versus the U.S. dollar in a specific range, and PEMEX recognizes a benefit if the euro depreciates up to a certain exchange rate, for each debt issue. Whereas, in order to mitigate the exchange rate risk caused by the coupons of these issues PEMEX entered into coupon-only swaps.

Additionally, PEMEX entered into, without cost, a structure which is composed of a cross-currency swap and the sale of a call option, in order to hedge the notional risk of a debt issue in Pound sterling for £450,000, guaranteeing complete protection up to a certain exchange rate and partial protection above that level.

PEMEX recorded a total net foreign exchange gain (loss) of Ps. 23,184,122, Ps. (254,012,743) and Ps. (154,765,574), for the years ended December 31, 2017, 2016 and 2015, respectively; these amounts include the unrealized foreign exchange gain (loss) associated with debt of Ps. 16,685,439, Ps. (243,182,764) and Ps. (152,554,454) for the years ended December 31, 2017, 2016 and 2015, respectively. The appreciation of the peso caused a total net foreign exchange gain because a significant part of PEMEX’s debt, 89.4% (principal only), as of December 31, 2017 is denominated in foreign currency. Unrealized foreign exchange gains and losses do not impact PEMEX’s cash flows. Due to the cash flow structure described above, the depreciation of the peso relative to the U.S. dollar does not affect PEMEX’s ability to meet U.S. dollar-denominated financial obligations and improves PEMEX’s ability to meet peso-denominated financial obligations. On the other hand, the appreciation of the peso relative to the U.S. dollar may increase PEMEX’s peso debt service costs on a U.S. dollar basis. PEMEX’s foreign exchange gain in 2017 was due to the appreciation of the peso, from Ps. 20.6640 = U.S. $1.00 on December 31, 2016 to Ps. 19.7867 = U.S. $1.00 on December 31, 2017. PEMEX’s foreign exchange loss in 2016 was due to the depreciation of the peso, from Ps. 17.2065 = U.S. $1.00 on December 31, 2015 to Ps. 20.6640 = U.S. $1.00 on December 31, 2016. PEMEX’s foreign exchange loss in 2015 was due to the depreciation of the peso, from Ps. 14.7180 = U.S. $1.00 on December 31, 2014 to Ps.17.2065 = U.S. $1.00 on December 31, 2015.

Certain of the PMI subsidiaries face market risks generated by fluctuations in foreign exchange rates. In order to mitigate these risks, the boards of directors of several of these companies have authorized a policy which stipulates that no more than 5% of a company’s total financial assets may be denominated in a currency other than its functional currency, unless the company owes a duty or expected payment in a currency other than its functional one. Accordingly, certain PMI subsidiaries will, from time to time, enter into DFIs in order to mitigate the risk associated with financing operations denominated in currencies other than their respective functional currency.

Finally, a significant amount of PMI Trading’s income and expenses, including the cost of sales and related sales costs, is derived from the trade of refined products, petrochemicals and gas liquids to PEMEX subsidiaries and third parties, whose prices are determined and are payable in U.S. dollars. PMI Trading’s exposure to foreign currency risk results primarily from the need to fund tax payments denominated in domestic currency, as well as certain related sales costs denominated in domestic currency.

PMI Trading believes it can adequately manage the risk created by the payment of taxes in domestic currency without the need to enter into hedging instruments because the exposure to this risk is marginal relative

F-86

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

to the total flows of U.S. dollar. In addition, in the event that a potential foreign exchange risk arises in connection with a commercial transaction, PMI Trading may implement risk mitigation measures by entering into DFIs.

iii. Hydrocarbon Price Risk

PEMEX periodically assesses its revenues and expenditures structure in order to identify the main market risk factors that PEMEX’s cash flows are exposed to in connection with international hydrocarbon prices. Based on this assessment, PEMEX monitors its exposure to the most significant risk factors and quantifies their impact on PEMEX’s financial balance.

PEMEX’s exports and domestic sales are directly or indirectly related to international hydrocarbon prices. Therefore, PEMEX is exposed to fluctuations in these prices. In terms of crude oil and natural gas, part of this risk is transferred to the Mexican Government under PEMEX’s current fiscal regime.

PEMEX continuously evaluates the implementation of risk mitigation strategies, including those involving the use of DFIs, while taking into account operational and economic constraints.

PEMEX’s exposure to hydrocarbon prices is partly mitigated by natural hedges between its inflows and outflows.

Since 2016, as a result of the changes in the PEMEX’s fiscal regime, its sensitivity to crude oil prices decreased. Nonetheless, PEMEX worked on a hedging strategy for the following years in order to reduce its exposure to drops in crude oil price.

In April 2017, PEMEX entered into a crude oil hedge to partially protect its cash flows from decreases in the Mexican crude oil basket price below that established in the Ley de Ingresos de la Federación (“Federal Revenue Law”). PEMEX hedged 409 thousand barrels per day from May to December 2017 for U.S. $133,503. As a result of this strategy PEMEX had an income of U.S. $205,705.

During the fourth quarter of 2017, PEMEX entered into a crude oil hedge to partially protect cash flows for the fiscal year 2018 from decreases in the Mexican crude oil basket price below the one established in the 2018 Federal Revenue Law. PEMEX hedged 440 thousand barrels per day from January to December 2018 for U.S. $449,898.

In 2015, PEMEX entered into various swaps in order to hedge the risk arising from the variations of the propane price of its imports. These DFIs were held over a percentage of the total imports volume with maturity dates in 2015. During 2017 and 2016, PEMEX did not enter into any propane import price swaps.

In addition to supplying natural gas, Pemex Industrial Transformation offers DFIs to its domestic customers in order to provide them with support to mitigate the risk associated with the volatility of natural gas prices. Until 2016, Pemex Industrial Transformation entered into DFIs with Mex Gas Supply, S.L. under the opposite position to those DFIs offered to its customers in order to mitigate the market risk it bears under such offered DFIs. Mex Gas Supply, S.L. then transferred the related price risk derived from the DFI position held with Pemex Industrial Transformation to international financial counterparties by entering into these opposite position DFIs with such parties. As of 2017, Pemex Industrial Transformation must enter into DFIs with Petróleos Mexicanos under the

F-87

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

opposite position to those DFIs offered to its customers, thereby replacing Mex Gas Supply, S.L. However, as of December 31, 2017, no DFIs have been entered into under this mechanism. Due to the above, Pemex Industrial Transformation maintains a negligible or even null exposure to market risk. These portfolios have VaR and Capital at Risk limits in order to limit market risk exposure.

PMI Trading faces market risk generated by the terms of the purchase and sale of refined products and natural gas liquids, as well as the volatility of oil prices. Accordingly, it frequently enters into DFIs in order to mitigate this risk, thereby reducing the volatility of its financial results.

iv. Risks relating to the portfolio of third-party shares

As of December 31, 2017, Petróleos Mexicanos does not hold any third-party shares of companies that do not participate in financial markets and, therefore, does not hold any related DFIs.

During 2017, PMI HBV liquidated the total shareholding in Repsol, S.A. (Repsol), which was 23,416,219 shares. Therefore, as of December 31, 2017, PEMEX does not hold any third-party shares and does not hold any related DFIs.

v. Market risk quantification

The quantification of market risk exposure in PEMEX’s financial instruments is presented below, in accordance with the applicable international risk management practices.

Interest rate risk quantification

The quantification of interest rate risk of investment portfolios is carried out by using the one-day horizon historical VaR, with a confidence level of 95%, over a period of one year. The VaR incorporates interest rate and spread risks. In addition, for portfolios in domestic currency, the VaR includes the inflation risk embedded in securities denominated in UDI. For portfolio management purposes, interest rate risk is mitigated by VaR limits.

As of December 31, 2017, the VaR of PEMEX’s investment portfolios was Ps. (10.82) for the Peso Treasury Portfolio, Ps. (44.95) for the Fondo Laboral Pemex Portfolio (“FOLAPE”), Ps. (7.17) for the Fideicomiso de Cobertura Laboral y de Vivienda Portfolio (“FICOLAVI”), Ps. (544.32) for the Mexican Peso Treasury Portfolio managed by Operadora de Fondos Nafinsa, S.A. de C.V. (“OFINSA”), and U.S. $0 for the U.S. Dollar Treasury Portfolio.

In addition to the exposure to interest rate fluctuations of the DFIs in which PEMEX is obligated to pay floating rates, PEMEX’s DFIs are exposed to MtM volatility as a result of changes in the interest rate curves used in their valuation.

Interest rate risk quantification was calculated for DFIs in conjunction with the interest rate risk quantification for the debt portfolio. The following table shows the sensitivity of PEMEX’s DFIs and debt portfolio to a parallel shift of 10 basis points (bp) over the zero coupon rate curves. The 10bp parallel shift may be used to estimate in a simple manner the impact for proportional values to this shift and was selected in accordance with market practices for financial risk management.

F-88

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

For the debt portfolio, interest rate risk sensitivity was calculated taking into account both the DFI interbank market yield curves and the PEMEX curves (which were also used to estimate the debt portfolios’ fair value). These metrics were calculated solely for informational purposes and are not used for portfolio management purposes because PEMEX does not intend to prepay its debt or terminate its DFIs early. Therefore, there is no interest rate risk arising from fixed rate obligations.

INTEREST RATE and CURRENCY DFIs

Interest rate sensitivity to + 10 bp
	Interbank Yield Curves							PEMEX Curves Sensitivity debt
Currency	Sensitivity debt		Sensitivity DFIs			Sensitivity net
in thousands U.S. dollars
CHF		3,144		(3,144	)		—		3,030
Euro		100,081		(84,962	)		15,119		82,839
Pound Sterling		7,691		(7,073	)		618		6,587
Yen		8,542		(3,972	)		4,570		6,877
Peso		43,774		2,039			45,813		42,012
UDI		16,496		(11,586	)		4,910		15,453
U.S. dollar		785,508		89,880			875,388		416,052

FX swaps were included in the calculation of the figures in the previous table, which were not traded as debt hedging.

In addition, PEMEX performed a retrospective sensitivity analysis of the impact on its financial statements for the years ended December 31, 2017, 2016 and 2015, in which PEMEX assumed either an increase or decrease of 25 basis points in the floating interest rates of its debt and corresponding hedges.

At December 31, 2017, 2016 and 2015, had market interest rates been 25 basis points higher, with all other variables remaining constant, net income for the year would have been Ps. 704,011, Ps. 841,024 and Ps. 922,268 lower for December 31, 2017, 2016 and 2015, respectively, primarily as a result of an increase in interest expense. Conversely, had market interest rates been 25 basis points lower, net income for the year would have been Ps. 704,011, Ps. 841,024 and Ps. 922,268 greater at December 31, 2017, 2016 and 2015, respectively, primarily as a result of a decrease in interest expense.

Exchange rate risk quantification

The investments of PEMEX’s portfolios do not face foreign exchange rate risk because the funds of such portfolios are used to meet obligations in pesos and U.S. dollars.

Currency DFIs are entered into in order to hedge exchange rate risk arising from debt flows in currencies other than pesos and U.S. dollars or inflation risk arising from debt flows in UDIs. However, due to the accounting treatment, net income is exposed to mark-to-market volatility as a result of changes in the exchange rates used in their valuation.

F-89

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Exchange rate risk quantification was calculated for DFIs in conjunction with the exchange rate risk quantification for the debt portfolio. The following table shows the sensitivity of PEMEX’s DFIs and debt portfolio to an increase of 1% to the exchange rates of currencies against the U.S. dollar. The 1% may be used to estimate in a simple manner the impact for proportional values to this increase and was selected in accordance with market practices for financial risk management.

For the debt portfolio, exchange rate risk sensitivity was calculated taking into account both, interbank market yield curves and the PEMEX curves. In addition, the table shows the one-day horizon historical VaR of the remaining open position, with a confidence level of 95%, over a period of one year. These metrics were calculated solely for informational purposes. Nevertheless, in order to carry out management activities related to its debt portfolio, PEMEX periodically conducts quantitative analyses in order to estimate the exchange rate risk exposure generated by its debt issuances. Based on these analyses, PEMEX has elected to enter into DFIs as an exchange rate risk mitigation strategy.

INTEREST RATE and CURRENCY DFIs

	Interbank Yield Curves											PEMEX Curves 1% Debt
Currency	1% Debt			1% DFIs		1% Net			VaR 95% Net
in thousands U.S. dollars
CHF		(13,943	)		13,943		—			—			(13,624	)
Euro		(187,988	)		165,894		(22,094	)		(19,744	)		(167,068	)
Pound Sterling		(13,822	)		13,042		(780	)		(666	)		(12,322	)
Yen		(16,914	)		11,470		(5,444	)		(4,398	)		(14,859	)
Peso		(135,974	)		1,409		(134,565	)		(162,336	)		(133,525	)
UDI		(29,485	)		25,358		(4,127	)		(5,038	)		(28,573	)

As shown in the table above, exchange rate risk derived from debt denominated in currencies other than pesos and U.S. dollars is almost fully hedged by DFIs.

The exchange rate risk exposure to the euro, Pound sterling and Japanese yen is result of the delta of the structures described above (Seagull Options and Calls).

FX swaps which were not traded as part of debt hedging were included in the calculation of the figures in the table above.

In addition, PEMEX performed a retrospective sensitivity analysis of the impact on its financial statements of the years ended December 31, 2017, 2016 and 2015, in which PEMEX assumed either an increase or decrease of 10% in the exchange rate between the U.S. dollar and peso in order to determine the impact on net income and equity as a result of applying these new rates to the monthly balances of assets and liabilities denominated in U.S. dollars.

At December 31, 2017, 2016 and 2015, had the peso depreciated against the U.S. dollar by 10% with other variables remaining constant, net income would have been Ps.149,669, Ps.124,512 and Ps.105,915 lower, respectively, primarily as a result of an increase in the exchange rate losses. However, had the peso appreciated against the U.S. dollar by 10%, net income for the period would have increased by Ps.149,669, Ps.124,512 and Ps.105,915, respectively, primarily as a result of the decrease in exchange rate losses.

F-90

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Hydrocarbon price risk quantification

Pemex Industrial Transformation occasionally faces market risk due to open positions arising from the mismatch between the DFI portfolio offered to domestic customers and hedges with international counterparties. As of December 31, 2017, Pemex Industrial Transformation’s natural gas DFI portfolio had no market risk exposure.

Market risk exposure is measured using the 20-day Delta-Gamma VaR methodology, with a confidence level of 95%, based on 500 daily observations; VaR and CaR are monitored and mitigated by pre-established limits.

It should be noted that sensitivity analyses were not carried out for other financial instruments, such as accounts receivable and payable (as defined in the financial reporting standards). Such accounts are cleared in short-term, and therefore market risk is considered to be nonexistent. Most of these accounts are related to hydrocarbon prices.

In accordance with the risk management regulatory framework that PMI Trading has implemented, VaR and the change in profit and loss by portfolio are calculated daily and compared to the maximum applicable limits in order to implement risk mitigation mechanisms as necessary.

PMI Trading’s global VaR associated with commodities market risk was U.S. $(8,789) as of December 31, 2017. This VaR was calculated using the historical method with a 99% confidence level, two-year history and a one-day horizon. The minimum VaR recorded on the year was U.S. $(4,720) (registered on October 17, 2017) and the maximum VaR recorded on the year was U.S. $(19,695) (registered on January 4, 2017). As of December 31, 2016, the global VaR was U.S. $(23,198).

The quantification of crude oil price risk is carried out by using the one-day horizon historical VaR, with a confidence level of 95%, over a period of one year. As of December 31, 2017, this was U.S. $0 as a result of the rise in the price of crude oil.

II. Credit Risk

When the fair value of a DFI is favorable to PEMEX, PEMEX faces the risk that the counterparty will not be able to meet its obligations. PEMEX monitors its counterparties’ creditworthiness and calculates the credit risk exposure for its DFIs. As a risk mitigation strategy, PEMEX only enters into DFIs with major financial institutions with a minimum credit rating of BBB-. These ratings are issued and revised periodically by risk rating agencies. Furthermore, PEMEX seeks to maintain a diversified portfolio of counterparties.

In order to estimate PEMEX’s credit risk exposure to each financial counterparty, the potential future exposure is calculated by projecting the risk factors used in the valuation of each DFI in order to estimate the MtM value for different periods, taking into account any credit risk mitigation provisions.

Moreover, PEMEX has entered into various long-term cross-currency swaps agreements with “recouponing” provisions (pursuant to which the payments on the swaps are adjusted when the MtM exceeds the relevant threshold specified in the swap), thereby limiting the exposure with its counterparties to a specific threshold amount. The specified thresholds were reached in three cross-currency swaps from the first to the fourth quarter of 2017, which were used to hedge the exchange rate exposure to the euro and in five cross-currency swaps during 2016, which were used to hedge the exchange rate exposure to the Pound sterling. This resulted in the cash settlement of such swaps and the resetting of swap terms to return their mark-to-market value to zero. During 2017, PEMEX did not enter into any cross-currency swap with these characteristics.

F-91

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

In addition, during 2016 PEMEX entered into long-term DFIs with mandatory early termination clauses (pursuant to which, at a given date and irrespective of the current MtM, the DFI will terminate and settle at the corresponding MtM, and PEMEX can either enter into a new DFI with the same counterparty or a new counterparty), which reduces the credit risk generated by the term of the DFI by bounding it to a specific date. As of December 31, 2017, PEMEX has entered into three euro swaps and two Japanese yen Seagull Option structures, with termination clauses in 2018 and 2021, respectively.

According to IFRS 13 “Fair Value Measurement,” the fair value or MtM value of DFIs must reflect the creditworthiness of the parties. Consequently, the fair value of a DFI takes into account the risk that either party may default on its obligation. In accordance with market best practices, PEMEX applies the credit value adjustment (“CVA”) method to calculate the fair value of its DFIs.

For each DFI, the CVA is calculated by determining the difference between the MtM and the estimated MtM adjusted for credit risk. In determining the credit risk, the CVA method takes into account the current market perception about the credit risk of both counterparties, using the following inputs: a) the MtM projection for each payment date based on forward yield curves; b) the implied default probability obtained from both, PEMEX and the counterparty credit default swaps’, at each payment date; and c) the default recovery rates of each counterparty.

The current and potential exposures, aggregated by credit rating, are as follows:

Maximum Credit Exposure by term in Petróleos Mexicanos
Rating	Current		Less than 1 year		1-3 years		3-5 years		5-7 years		7-10 years		More than 10 years
in thousands U.S. dollars
A		257,424		976,230		1,298,110		1,314,296		578,548		482,959		—
A-		138,850		235,594		191,681		228,801		223,751		257,465		—
BBB+		310,705		1,010,356		1,540,015		1,349,311		1,243,898		1,115,559		78,831
BBB		2,183		18,626		20,064		18,092		—		—		—

PEMEX also faces credit risk derived from its investments. As of December 31, 2017, the notional amounts of investments in domestic currency, organized by the credit ratings of the issuances, were as follows:

Credit rating of issuances*	Notional amount
mxAAA		Ps.        811,548
mxAA		200,876
mxA		271,275
* Minimum S&P, Moody’s and Fitch credit rating.
National Credit Rating Scale.
Does not include investments in Mexican Government bonds.

The table above does not include domestic currency Mexican Government bonds because these issuances are considered not to carry default risk in this currency.

PEMEX held an investment in a note linked to United Mexican States’ credit risk that was issued by a U.S. financial institution with a BBB+ credit rating. This note matured in June 2016 and had a face value of U.S. $108,000. As of December 31, 2017, PEMEX does not hold an investment in structured notes.

F-92

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Furthermore, by means of its credit guidelines for DFI operations, Pemex Industrial Transformation has significantly reduced its credit risk exposure related to the DFIs offered to its customers to assist them in mitigating the risk associated with the volatility of natural gas.

In order to qualify for these DFIs, Pemex Industrial Transformation’s customers must be party to a current natural gas supply contract and sign a domestic master derivative agreement.

Additionally, beginning on October 2, 2009, DFIs with these customers must be initially secured by cash deposits, letters of credit or other collateral provisions, as required. In accordance with these guidelines, in the event that a client does not meet its payment obligations, DFIs related to this client are terminated, rights to collateral are exercised and, if the collateral is insufficient to cover the fair value, natural gas supply is suspended until the payment is made.

On August 20, 2014, certain amendments to the credit guidelines were enacted, which allowed Pemex-Gas and Petrochemicals, and now Pemex Industrial Transformation, to offer to its clients with an adequate credit rating, based on an internal financial and credit assessment, DFIs with an exemption from collateral requirements up to certain amount through a credit line approved by the credit committee. Moreover, if the credit line is insufficient to cover each client’s exposure, the client is obligated to deposit collateral. If a client suffers an event of default, DFIs related to this client are terminated early and natural gas supply is suspended until the payment is made.

As of December 31, 2017, Pemex Industrial Transformation’s DFIs had a fair value of U.S. $1,464 (deferred premiums included) for clients with exempted credit lines and U.S. $8,183 for clients with guaranteed credit lines. The total amount of exempt credit lines rose to U.S. $117,956, representing 1% usage of available exempt credit lines, while the total amount of guaranteed credit lines rose to U.S. $930,199, representing a 1% usage of available guaranteed credit lines.

As of December 31, 2017, the overdue accounts of natural gas customers in the industrial and distribution sectors accounted for less than 1.00% of the total sales of Pemex Industrial Transformation.

As of December 31, 2017, Pemex Industrial Transformation had open DFIs with 8 customers. Of the total volume (in millions of British thermal units or MMBtu) of DFIs, industrial customers represented 100%.

As of December 31, 2017 and 2016, Pemex Industrial Transformation had not provided any collateral for DFIs entered into to hedge its DFIs with customers. This was due to the following: (i) natural gas prices maintained levels below the strike price, which has kept the credit limits within the set limits; and (ii) when certain DFIs matured, Pemex-Gas and Basic Petrochemicals, and now Pemex Industrial Transformation, had used domestic customers’ payments to meet its international obligations.

The potential future exposure of Mex Gas Supply, S.L.’s DFI portfolio was calculated in an analogous manner to the analysis of Petróleos Mexicanos’ DFI positions. The current and potential exposure, aggregated by credit rating, is as follows:

Maximum Credit Exposure by term in Pemex Industrial Transformation
Rating	Current		Less than 1 year		1-3 years		3-5 years		5-7 years		7-10 years		More than 10 years
in thousands U.S. dollars
A		27		27		—		—		—		—		—
A-		541		541		306		—		—		—		—
BBB+		25		25		1		—		—		—		—

F-93

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

PMI Trading’s credit risk associated with DFI transactions is mitigated through the use of futures and standardized instruments that are cleared through CME-ClearPort.

III. Liquidity Risk

Through its debt planning and the purchase and sale of U.S. dollars, PEMEX currently preserves a cash balance at a level of liquidity in domestic currency and U.S. dollars that is considered adequate to cover its investment and operating expenses, as well as other payment obligations. In order to preserve a cash balance at a suitable level, in December of 2017, PEMEX entered into ten FX swaps of the peso against U.S. dollar for an aggregate amount of U.S. $3,000,000.

In addition, PEMEX has acquired committed revolving credit lines in order to mitigate liquidity risk, two of which provide access to Ps. 3,500,000 and Ps. 20,000,000 with expiration dates in June and November 2019, respectively; and three others that each provide access to U.S. $1,500,000, U.S. $3,250,000 and U.S. $1,950,000 with expiration dates in December 2019, February 2020 and January 2021, respectively.

Finally, the investment strategies of PEMEX’s portfolios are structured by selecting time horizons that consider each currency’s cash flow requirements in order to preserve liquidity.

Certain PMI subsidiaries mitigate their liquidity risk through several mechanisms, the most important of which is the centralized treasury or “in-house bank,” which provides access to a syndicated credit line for up to U.S. $700,000 and cash surplus capacity in the custody of the centralized structure. In addition, certain PMI subsidiaries have access to bilateral credit lines from financial institutions for up to U.S. $650,000.

These companies monitor their cash flow on a daily basis and protect their creditworthiness in the financial markets. Liquidity risk is mitigated by monitoring the maximum/minimum permissible financial ratios as set forth in the policies approved by each company’s board of directors.

The following tables show the cash flow maturities as well as the fair value of PEMEX’s debt and DFI portfolios as of December 31, 2017 and 2016. It should be noted that:

• For debt obligations, these tables present principal cash flow and the weighted average interest rates for fixed rate debt.

• For interest rate swaps, cross currency swaps, currency options and currency forwards, these tables present notional amounts and weighted average interest rates by expected (contractual) maturity dates.

• Weighted average variable rates are based on implied forward rates obtained from the interbank market yield curve at the reporting date.

• For natural gas DFIs, volumes are presented in millions of British thermal unit (MMBtu), and fixed average and strike prices are presented in U.S. dollars per MMBtu.

• For crude oil, volumes are presented in millions of barrels, and fixed average and strike prices are presented in U.S. dollars per barrel.

• A DFI’s fair value includes CVA and is calculated based on market quotes obtained from market sources such as Bloomberg. Forward curves and implied volatilities for natural gas and crude oil are supplied by the Kiodex Risk Workbench platform.

F-94

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

• For PMI Trading, the prices used in commercial transactions and DFIs are published by reputable sources that are widely used in international markets, such as CME-NYMEX, Platts and Argus, among others.

• Fair value is calculated internally, either by discounting cash flows with the corresponding zero-coupon yield curve in the original currency, or through other standard methodologies commonly applied in financial markets for specific instruments.

• For all instruments, tables are based on the contract terms in order to determine the future cash flows that are categorized by expected maturity dates.

This information is presented in thousands of pesos, except as noted.

F-95

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Quantitative Disclosure of Debt Cash Flow’s Maturities as of December 31, 2017⁽¹⁾

	Year of expected maturity date
	2018		2019		2020		2021		2022		2023 thereafter		Total carrying value			Fair value
Liabilities
Outstanding debt
Fixed rate (U.S. dollars)	Ps	53,465,817	Ps	59,498,256	Ps	60,290,621	Ps	95,232,448	Ps	84,076,050	Ps	808,836,547	Ps	1,161,399,739		Ps	. 1,213,404,769
Average interest rate (%)														5.7747	%
Fixed rate (Japanese yen)		—		—		—		—		—		19,296,607		19,296,607			18,040,398
Average interest rate (%)														1.3485	%
Fixed rate (Pounds)		—		—		—		—		9,345,839		11,952,816		21,298,655			24,381,394
Average interest rate (%)														5.7246	%
Fixed rate (pesos)		—		—		10,033,017		20,376,655		1,999,098		88,349,072		120,757,842			171,683,692
Average interest rate (%)														7.4876	%
Fixed rate (UDIs)		—		18,477,076		4,764,175		3,874,313		—		30,081,647		57,197,211			56,536,905
Average interest rate (%)														2.7458	%
Fixed rate (euros)		1,043		32,042,196		30,801,894		41,508,857		23,655,950		171,255,634		299,265,574			330,573,998
Average interest rate (%)														3.6736	%
Fixed rate (Swiss Francs)		4,565,075		6,088,686		12,149,953		3,046,567		—		—		25,850,281			26,957,785
Average interest rate (%)														1.8387	%
Fixed rate (Australian dollars)		—		—		—		—		—		—		—			—
Average interest rate (%)		—		—		—		—		—		—		—			—
Total fixed rate debt		58,031,935		116,106,214		118,039,660		164,038,840		119,076,937		1,129,772,323		1,705,065,909			1,841,578,940
Variable rate (U.S. dollars)		58,364,536		15,302,101		62,289,546		12,809,666		31,289,725		18,379,557		198,435,131			206,254,219
Variable rate (Japanese yen)		—		—		11,244,800		—		—		—		11,244,800			11,361,079
Variable rate (pesos)		8,734,371		27,995,083		18,341,742		8,459,163		8,394,483		19,125,764		91,050,606			94,188,981
Total variable rate debt		67,098,907		43,297,184		91,876,088		21,268,829		39,684,208		37,505,321		300,730,537			311,804,280
Total debt	Ps	. 125,130,842	Ps	. 159,403,398	Ps	. 209,915,748	Ps	. 185,307,669	Ps	. 158,761,145	Ps	.1,167,277,644	Ps	. 2,005,796,446		Ps	.2,153,383,220

Note: Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2017 of: Ps. 19.7867 = U.S. $1.00; Ps. 0.1757 = 1.00 Japanese yen; Ps. 26.7724 = 1.00 Pound sterling; Ps. $ 5.934551 = 1.00 UDI; Ps. 23.7549 = 1.00 euro; Ps. 20.2992 = 1.00 Swiss Franc; and Ps. 15.4752 = 1.00 Australian dollar.

Source: PEMEX

F-96

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Quantitative Disclosure of Debt Cash Flow’s Maturities as of December 31, 2016⁽¹⁾

	Year of expected maturity date
	2017		2018		2019		2020		2021		2022 thereafter		Total carrying value			Fair value
Liabilities
Outstanding debt
Fixed rate (U.S. dollars)		Ps 15,759,027	Ps	86,161,096	Ps	65,642,616	Ps	62,440,943	Ps	98,858,992	Ps	826,093,574	Ps	1,154,956,248		Ps	1,137,936,275
Average interest rate (%)														5.6541	%
Fixed rate (Japanese yen)		517,286		—		—		—		—		19,459,306		19,976,592			17,336,203
Average interest rate (%)														1.3665	%
Fixed rate (Pounds)		—		—		—		—		—		8,825,434		8,825,434			11,373,345
Average interest rate (%)														8.2500	%
Fixed rate (pesos)		—		—		—		10,048,950		20,457,671		90,393,507		120,900,128			160,930,040
Average interest rate (%)														7.4878	%
Fixed rate (UDIs)		—		—		17,319,897		4,464,787		3,630,557		28,288,180		53,703,421			50,809,979
Average interest rate (%)														4.0559	%
Fixed rate (euros)		26,006,880		—		29,198,138		28,061,554		—		123,886,644		207,153,216			216,100,006
Average interest rate (%)														3.9581	%
Fixed rate (Swiss Francs)		—		4,539,022		6,056,338		12,102,748		3,031,480		—		25,729,588			26,469,543
Average interest rate (%)														1.8385	%
Fixed rate (Australian dollars)		2,232,195		—		—		—		—		—		2,232,195			2,346,390
Average interest rate (%)		—		—		—		—		—		—		6.1250	%		—
Total fixed rate debt		44,515,388		90,700,118		118,216,989		117,118,982		125,978,700		1,096,946,645		1,593,476,822			1,623,301,781
Variable rate (U.S. dollars)		38,811,320		27,907,661		15,984,547		52,726,647		13,366,336		45,385,885		194,182,396			195,838,382
Variable rate (Japanese yen)		—		—		—		11,341,440		—		—		11,341,440			11,025,531
Variable rate (euros)		—		—		—		—		—		—		—			—
Variable rate (pesos)		65,024,075		8,742,191		28,007,709		18,347,822		8,468,176		27,764,693		156,354,666			158,109,920
Total variable rate debt		103,835,395		36,649,852		43,992,256		82,415,909		21,834,512		73,150,578		361,878,502			364,973,833
Total debt	Ps.	148,350,783	Ps.	127,349,970	Ps.	162,209,245	Ps.	199,534,891	Ps.	147,813,212	Ps.	1,170,097,223	Ps.	1,955,355,324		Ps.	1,988,275,614

Note: Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2016 of: Ps. 20.664 = U.S. $1.00; Ps. 0.17721 = 1.00 Japanese yen; Ps. 25.30513 = 1.00 Pound sterling; Ps. $ 5.562883 = 1.00 UDI; Ps. 21.6724 = 1.00 euro; Ps. 20.19744= 1.00 Swiss Franc; and Ps. 14.88428 = 1.00 Australian dollar.

Source: PEMEX

F-97

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Quantitative Disclosure of Cash Flow’s Maturities from Derivative Financial Instruments Held or Issued for Purposes Other than Trading as of December 31, 2017⁽¹⁾⁽²⁾

	Year of expected maturity date																		Total Notional Amount		Fair Value(3)
	2018			2019			2020			2021			2022			2023 Thereafter
Hedging instruments(2)(4)
Interest rate DFIs
Interest rate swaps (U.S. dollars)
Variable to fixed		Ps. 4,704,170			Ps. 4,717,321			Ps. 4,730,857			Ps. 4,686,396			Ps 4,570,070			Ps 10,143,209			Ps. 33,552,022		Ps. 388,851
Average pay rate		3.16	%		3.18	%		3.20	%		3.22	%		3.26	%		3.48	%		N.A.		N.A.
Average receive rate		3.19	%		3.44	%		3.69	%		3.81	%		3.95	%		4.48	%		N.A.		N.A.
Interest rate swaps (pesos)
Variable to fixed		—			—			—			—			—			—			—		—
Average pay rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Average receive rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Currency DFIs
Cross-currency swaps
Receive euros/Pay U.S. dollars		—			29,898,198			28,719,208			36,902,690			21,302,856			161,617,172			278,440,124		19,065,727
Receive Japanese yen/ Pay U.S. dollars		—			—			13,039,563			—			—			4,775,551			17,815,114		(1,670,533	)
Receive Pounds sterling/ Pay U.S. dollars		—			—			—			—			10,310,216			11,706,999			22,017,215		1,151,096
Receive UDI/ Pay pesos		—			23,740,341			7,292,520			3,000,000			—			20,605,166			54,638,028		(4,720,592	)
Receive Swiss francs/ Pay U.S. dollars		4,535,474			6,501,082			11,548,658			2,994,374			—			—			25,579,588		400,316
Receive Australian dollars/ Pay U.S. dollars		—			—			—			—			—			—			—		—
Currency Options
Buy Put, Sell Put and Sell Call on Japanese yen		—			—			—			—			—			14,046,320			14,046,320		48,715
Buy call, Sell call and Sell Put on euros		—			—			—			41,567,998			—			59,382,855			100,950,853		4,919,444
Sell Call on Pound sterling		—			—			—			—			—			12,031,728			12,031,728		(239,626	)
Currency Forwards
Receive U.S. dollars / Pay pesos		59,360,100			—			—			—			—			—			59,360,100		(2,006,461	)

N.A. = not applicable.

Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2017 of: Ps. 19.7867 = U.S. $1.00 and Ps. 23.7549 = 1.00 euro.

(2) PEMEX’s management uses these DFIs to hedge market risk; however, these DFIs do not qualify for accounting purposes as hedges and are recorded in the financial statements as entered into for trading purposes.

(3) Positive numbers represent a favorable fair value to PEMEX.

(4) PMI’s risk management policies and procedures establish that DFIs should be used only for hedging purposes; however DFIs are not recorded as hedges for accounting purposes.

Source: PEMEX

F-98

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Quantitative Disclosure of Cash Flow’s Maturities from Derivative Financial Instruments Held or Issued for Purposes Other than Trading as of December 31, 2016⁽¹⁾⁽²⁾

	Year of expected maturity date																		Total Notional Amount		Fair Value(3)
	2017			2018			2019			2020			2021			2022 Thereafter
Hedging instruments(2)(4)
Interest rate DFIs
Interest rate swaps (U.S. dollars)
Variable to fixed		Ps. 4,899,645			Ps. 4,912,743			Ps. 4,926,477			Ps. 4,940,613			Ps 4,894,180			Ps 15,365,634			Ps. 39,939,292		Ps. 164,716
Average pay rate		2.76	%		2.66	%		3.35	%		3.83	%		4.04	%		4.57	%		N.A.		N.A.
Average receive rate		2.95	%		2.99	%		3.03	%		3.06	%		3.11	%		3.33	%		N.A.		N.A.
Interest rate swaps (pesos)
Variable to fixed		—			—			—			—			—			—			—		—
Average pay rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Average receive rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Currency DFIs
Cross-currency swaps
Receive euros/Pay U.S. dollars		34,775,198			—			31,223,821			29,992,556			—			133,024,913			229,016,488		(16,484,533	)
Receive Japanese yen/ Pay U.S. dollars		532,711			—			—			17,697,534			—			4,987,289			23,217,534		(6,132,633	)
Receive Pounds sterling/ Pay U.S. dollars		—			—			—			—			—			10,767,349			10,767,349		(211,207	)
Receive UDI/ Pay pesos		—			—			23,740,341			3,540,220			3,000,000			14,313,198			44,593,759		(2,132,236	)
Receive Swiss francs/ Pay U.S. dollars		—			4,736,567			6,789,326			12,060,700			3,127,139			—			26,713,732		(789,449	)
Receive Australian dollars/ Pay U.S. dollars		2,459,429			—			—			—			—			—			2,459,429		(126,796	)
Currency Options
Buy Put, Sell Put and sell Call on yen		—			—			—			—			—			14,133,580			14,133,580		(301,131	)

N.A. = not applicable.

Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2016 of: Ps. 20.664 = U.S. $1.00 and Ps. 21.6724 = 1.00 euro.

(2) PEMEX’s management uses these DFIs to hedge market risk; however, these DFIs do not qualify for accounting purposes as hedges and are recorded in the financial statements as entered into for trading purposes.

(3) Positive numbers represent a favorable fair value to PEMEX.

(4) PMI’s risk management policies and procedures establish that DFIs should be used only for hedging purposes; however DFIs are not recorded as hedges for accounting purposes.

Source: PEMEX

F-99

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

B. Fair value of derivative financial instruments

PEMEX periodically evaluates its exposure to international hydrocarbon prices, interest rates and foreign currencies and uses derivative instruments as a mitigation mechanism when potential sources of market risk are identified.

PEMEX monitors the fair value of its DFI portfolio on a periodic basis. The fair value represents the price at which one party would assume the rights and obligations of the other and is calculated for DFIs through models commonly used in the international financial markets, based on inputs obtained from major market information systems and price providers. As a result of this monitoring, PEMEX does not employ an independent third party to perform the valuation.

PEMEX’s DFIs portfolio is composed primarily of swaps, the prices of which are estimated by discounting flows using the appropriate factors and contains no exotic instruments that require numerical approximations for their valuation.

Embedded derivatives

In accordance with established policies, PEMEX has analyzed the different contracts it has entered into and has determined that according to the terms thereof, none meet the criteria necessary to be classified as embedded derivatives. Accordingly, as of December 31, 2017 and 2016, PEMEX did not recognize any embedded derivatives (foreign currency or index).

Accounting treatment

PEMEX enters into derivatives transactions with the sole purpose of hedging financial risks related to its operations, firm commitments, planned transactions and assets and liabilities recorded on its statement of financial position. Nonetheless, some of these transactions do not qualify for hedge accounting treatment because they do not meet the requirements of the accounting standards for designation as hedges. They are therefore recorded in the financial statements as non-hedge instruments or as instruments entered into for trading purposes, despite the fact that their cash flows are offset by the cash flows of the positions (assets or liabilities) to which they relate. As a result, the changes in their fair value are recognized in the “Derivative financial instruments (cost) income, net” line item in the consolidated statement of comprehensive income.

As of December 31, 2017 and 2016, the net fair value of PEMEX’s DFIs (including both DFIs that have not reached maturity and those that have reached maturity but have not been settled), recognized in the consolidated statement of financial position, was Ps. 12,367,475 and Ps. (26,010,486), respectively. As of December 31, 2017 and 2016, PEMEX did not have any DFIs designated as hedges.

The following table shows the fair values and notional amounts of PEMEX’s OTC DFIs that were designated as non-hedges for accounting purposes and entered into for trading purposes as of December 31, 2017 and 2016. It should be noted that:

• A DFI’s fair value includes CVA and is calculated based on market quotes obtained from market sources such as Bloomberg. Forward curves and implied volatilities for natural gas and crude oil are supplied by the Kiodex Risk Workbench platform.

• Fair value is calculated internally, either by discounting cash flows with the corresponding zero-coupon yield curve, in the original currency, or through other standard methodologies commonly applied in the financial markets for certain specific instruments.

• The information is presented in thousands of pesos (except as noted).

F-100

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

		December 31, 2017						December 31, 2016
DFI	POSITION	Notional Amount			Fair Value			Notional Amount			Fair Value
Interest rate swaps	PEMEX pays fixed in U.S. dollar and receives floating in 3-month U.S. dollar LIBOR + spread.		Ps.16,695,028			Ps.   79,448			Ps.20,018,250		Ps.	(90,451	)
Interest rate swaps	PEMEX pays fixed in U.S. dollar and receives floating in 6-month U.S. dollar LIBOR + spread.		15,433,626			332,273			18,132,660			312,210
Cross-currency swaps	PEMEX pays fixed in pesos and receives notional in UDI.		23,740,341			(4,504,151	)		23,740,341			(4,815,373	)
Cross-currency swaps	PEMEX pays the 28-day TIIE + spread in pesos and receives fixed in UDI.		30,897,687			(216,441	)		20,853,418			2,683,138
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in Japanese yen.		4,775,551			134,461			5,520,000			(116,507	)
Cross-currency swaps	PEMEX pays floating in 6-month U.S. dollar LIBOR + spread and receives floating in 6-month yen LIBOR + spread.		13,039,563			(1,804,993	)		17,697,534			(6,016,126	)
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in euro.		278,440,124			19,065,727			229,016,488			(16,484,533	)
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in Pound sterling.		11,706,999			590,113			—			—
Cross-currency swaps	PEMEX pays floating in 6-month U.S. dollar LIBOR + spread and receives fixed in Pound sterling.		10,310,216			560,982			10,767,349			(211,207	)
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in CHF.		25,579,588			400,316			26,713,732			(789,449	)
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in AUD.		—			—			2,459,429			(126,796	)
Currency Options	PEMEX Buy Put, Sell Put and Sell Call on Japanese yen.		14,046,320			48,715			14,133,580			(301,131	)
Currency Options	PEMEX Buy call, Sell call and Sell Put on euros.		100,950,853			4,919,444			—			—
Currency Options	PEMEX Sell Call on Pound sterling		12,031,728			(239,626	)		—			—
Currency Forward	PEMEX pays Pesos and receives U.S. dollar.		59,360,100			(2,006,461	)		—			—
Natural gas swaps	PEMEX receives fixed.		(51,724	)		6,934			(160,214	)		(25,145	)
Natural gas swaps	PEMEX receives floating.		50,846			(6,114	)		157,545			27,869
Natural gas options	PEMEX Long Call.		18,625			398			73,653			11,548
Natural gas options	PEMEX Short Call.		(18,625	)		(397	)		(73,653	)		(11,488	)
Interest rate swaps	PEMEX pays fixed in U.S. dollar and receives floating in U.S. dollar LIBOR 1M.		1,423,368			(22,870	)		1,788,382			(57,043	)
						Ps.17,337,760					Ps.	(26,010,486	)

	December 31, 2017					December 31, 2016
DFI	Volume (MMb)		Fair Value			Volume (MMb)		Fair Value
Crude Oil Options		153.56	Ps.	(5,010,187	)		—		—

F-101

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

			December 31, 2017					December 31, 2016
DFI	Market		Volume (MMb)		Fair value			Volume (MMb)		Fair value
Futures		Exchange traded		2.1	Ps	. (141,693	)		—	Ps.	—
Petroleum Products Swaps		Exchange traded		1.3	Ps	.   (99,680	)		4.1	Ps.	(688,016	)

Notes: Numbers may not total due to rounding.

(1) The fair value of the Futures and the Petroleum Products Swaps, was recognized as “Cash and cash equivalents” in the statement of financial position because PEMEX considered these financial assets to be fully liquid.

The exchange rate for U.S. dollars as of December 31, 2017 and 2016 was Ps. 19.7867 and Ps. 20.6640 per U.S. dollar, respectively. The exchange rate for euros as of December 31, 2017 and 2016 was Ps. 23.7549 and Ps. 21.6724 per euro, respectively.

For the years ended December 31, 2017, 2016 and 2015, PEMEX recognized a net gain (loss) of Ps. 25,338,324, Ps. (14,000,987) and Ps. (21,449,877), respectively, in the “Derivative financial instruments (cost) income, net” line item with respect to DFIs treated as instruments entered into for trading purposes.

The following table presents the fair value of PEMEX’s DFIs that are showed on the consolidated statement of financial position in derivative financial instruments (including both DFIs that have not reached maturity and those that have reached maturity but have not been settled), as of December 31, 2017 and 2016:

	Derivatives assets Fair value
	2017		2016
Derivatives not designated as hedging instruments
Crude oil options	Ps.	397,630	Ps.	—
Currency options		4,968,159		—
Natural gas options		398		11,548
Cross-currency swaps		24,126,452		4,503,550
Natural gas swaps		7,003		30,162
Propane swaps		—		—
Interest rate swaps		411,721		312,210
Others		202,091		—
Total derivatives not designated as hedging instruments		30,113,454		4,857,470
Total assets	Ps.	30,113,454	Ps.	4,857,470

F-102

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

	Derivatives liabilities Fair value
	2017			2016
Derivatives not designated as hedging instruments
Forwards	Ps.	(2,006,461	)	Ps.	—
Futures		—			—
Crude oil options		(5,407,817	)		—
Currency options		—			(301,131	)
Natural gas options		(397	)		(11,488	)
Cross-currency swaps		(10,301,983	)		(30,380,405	)
Natural gas swaps		(6,182	)		(27,438	)
Propane swaps		—			—
Interest rate swaps		(22,870	)		(147,494	)
Others		(269	)		—
Total derivatives not designated as hedging instruments		(17,745,979	)		(30,867,956	)
Total liabilities	Ps.	(17,745,979	)	Ps.	(30,867,956	)
Net total	Ps.	12,367,475		Ps.	(26,010,486	)

The following tables present the net gain (loss) recognized in income on PEMEX’s DFIs for the years ended December 31, 2017, 2016 and 2015, in the consolidated statement of comprehensive income which is presented in the line “Derivative financial instruments (cost) income, net”:

Derivatives not designated as hedging instruments	Amount of gain (loss) recognized in the Statement of comprehensive income
	2017			2016			2015
Forwards	Ps.	(1,976,241	)	Ps.	—		Ps.	—
Futures		(779,950	)		(1,925,969	)		1,387,177
Crude oil options		(3,771,604	)		—			—
Currency options		5,255,931			(298,789	)		—
Natural gas options		673			(671	)		4,786
Cross-currency swaps		27,747,290			(11,633,605	)		(21,358,898	)
Natural gas swaps		1,780			831			4,355
Propane swaps		—			(3,805	)		(1,136,188	)
Interest rate swaps		(34,306	)		(138,979	)		(351,109	)
Others		(1,105,249	)		—			—
Total	Ps.	25,338,324		Ps.	(14,000,987	)	Ps.	(21,449,877	)

C. Fair value hierarchy

PEMEX values its DFIs under standard methodologies commonly applied in the financial markets. PEMEX’s related assumptions therefore fall under Level 2 of the fair value hierarchy for market participant assumptions, as described below.

The fair values determined by Level 1 inputs utilize quoted prices in financial markets for identical assets or liabilities. Fair values determined by Level 2 inputs are based on quoted prices for similar assets or liabilities in

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

financial markets, and inputs other than quoted prices that are observed for the assets or liabilities. Level 3 inputs are unobservable inputs for the assets or liabilities, and include situations where there is little, if any, market activity for the assets or liabilities.

Management uses appropriate valuation techniques based on the available inputs to measure the fair values of PEMEX’s applicable assets and liabilities.

When available, PEMEX measures fair value using Level 1 inputs, because they generally provide the most reliable evidence of fair value.

The following tables present information about PEMEX’s financial assets and liabilities measured at fair value and indicate the fair value hierarchy of the inputs utilized to determine the fair values as of December 31, 2017 and 2016.

	Fair value hierarchy							Total as of 2017
	Level 1		Level 2			Level 3
Assets:
Derivative financial instruments	Ps.	—	Ps.	30,113,454		Ps.	—	Ps.	30,113,454
Available-for-sale financial assets		—		1,056,918			—		1,056,918
Liabilities:
Derivative financial instruments		—		(17,745,979	)		—		(17,745,979	)
	Fair value hierarchy							Total as of 2016
	Level 1		Level 2			Level 3
Assets:
Derivative financial instruments	Ps.	—	Ps.	4,857,470		Ps.	—	Ps.	4,857,470
Available-for-sale financial assets		6,463,096		2,417,123			—		8,880,219
Liabilities:
Derivative financial instruments		—		(30,867,956	)		—		(30,867,956	)

When market quotes are not available to measure the fair value of PEMEX’s DFIs, PEMEX uses Level 2 inputs to calculate the fair value based on quotes from major market sources. These market quotes are then adjusted internally using standard market pricing models for interest rate, currency, equity and commodities derivatives.

F-104

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The following table shows the carrying value and the estimated fair value of the remaining financial assets and liabilities, which are not valued at fair value, as of December 31, 2017 and 2016:

	2017				2016
	Carrying value		Fair value		Carrying value		Fair value
Assets:
Cash and cash equivalents	Ps.	97,851,754	Ps.	97,851,754	Ps.	163,532,513	Ps.	163,532,513
Accounts receivable, net		170,645,234		170,645,234		133,220,527		133,220,527
Long-term notes receivable		148,492,909		148,492,909		148,607,602		148,607,602
Liabilities:
Suppliers		139,955,378		139,955,378		151,649,540		151,649,540
Accounts and accrued expenses payable		23,211,401		23,211,401		18,666,607		18,666,607
Short-term debt and current portion of long-term debt		157,209,467		157,209,467		176,166,188		176,166,188
Long-term debt		1,880,665,604		1,996,173,753		1,807,004,542		1,812,109,426

The fair values of the financial current assets and current liabilities presented in the table above are included for informational purposes.

The fair values of current financial assets and short-term liabilities are equal to their nominal values because, due to their short-term maturities, their nominal values are very close to their corresponding fair values.

The fair value of long-term debt is estimated using quotes from major market sources which are then adjusted internally using standard market pricing models. As a result of relevant assumptions, estimated fair values do not necessarily represent the actual terms at which existing transactions could be liquidated or unwound.

The information related to “Cash and cash equivalents”, “Accounts receivable, net”, “Available-for-sale financial assets”, “Long-term notes receivable” and “Debt” is described in the following notes, respectively:

• Note 6, Cash, cash equivalents and restricted cash;

• Note 7, Accounts receivable, net;

• Note 10, Available-for-sale financial assets;

• Note 14, Long-term notes receivable and other; and

• Note 15, Debt.

NOTE 17. EMPLOYEE BENEFITS

Until December 31, 2015, Petróleos Mexicanos and Subsidiary Entities only had defined benefit pension plans for the retirement of its employees, to which only Petróleos Mexicanos and the Subsidiary Entities contribute. Benefits under these plans are based on an employee’s salary and years of service completed at retirement. As of January 1, 2016, Petróleos Mexicanos and Subsidiary Entities also has a defined contribution pension plan, in which both Petróleos Mexicanos and Subsidiary Entities and the employee contribute to an employee’s individual account.

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Benefits under the defined benefit plan are mainly based on the years of service completed by the employee, and their remuneration at the date of retirement. The obligations and costs of these plans are recognized based on an actuarial valuation prepared by independent experts. Within the regulatory framework of plan assets, there are no minimum funding requirements. Petróleos Mexicanos and the Subsidiary Entities have established additional plans to cover post-employment benefits, which are based on actuarial studies prepared by independent experts and which include disability, post-mortem pension and the death of retired employees.

As of December 31, 2017, Petróleos Mexicanos and Subsidiary Entities funded its employees benefits through Mexican trusts, the resources of which come from the retirement line item of PEMEX’s annual budget (an operating expense), or any other line item that substitutes or relates to this line item, or that is associated to the same line item and the interests, dividends or capital gains obtained from the investments of the trusts.

The following table show the amounts associated with PEMEX’s labor obligations:

	December 31,
Defined Benefits Liabilities	2017		2016
Liability for defined benefits at retirement and post-employment at the end of the year		Ps. 1,241,072,307		Ps. 1,202,624,665
Liability for other long-term benefits		17,363,815		17,784,771
Total liability for defined benefits recognized in the consolidated statement of financial position at the end of the year		Ps. 1,258,436,122		Ps. 1,220,409,436

The following tables contain detailed information regarding PEMEX’s retirement and post-employment benefits:

	December 31,
Changes in the liability for defined benefits	2017			2016
Liability for defined benefits at the beginning of the year		Ps. 1,202,624,665			Ps. 1,258,480,019
Recognition of the modifications in pensions plan		8,327			(571,713	)
Current Service cost		13,079,341			23,111,918
Net interest		95,402,917			90,527,624
Past service costs		—			(33,244	)
Defined benefits paid by the fund		(5,105,669	)		(4,892,767	)
Actuarial (gains) losses in other comprehensive results due to:
Change in financial assumptions		47,182,448			(149,533,263	)
Change in demographic assumptions		(70,012,604	)		4,842,109
For experience during the year		10,272,231			36,103,857
In plan assets during the year		(453,206	)		285,123
Remeasurements		26,417			(1,742	)
Contributions paid to the fund		(51,952,560	)		(55,693,256	)
Defined benefit liabilities at end of year		Ps. 1,241,072,307			Ps. 1,202,624,665

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

In 2017 and 2016, the net actuarial gains recognized in other comprehensive income (loss) net of income deferred tax were Ps. 12,038,710 and Ps. 106,387,640, respectively, related to retirement and post-employment benefits, not including the normal year to year increase in obligations based on changes in population, age, seniority, wages, pensions and benefits. The decrease in losses in 2017 was mainly due to the decrease in the discount and return on plan assets rates, from 8.17% in 2016 to 7.89% in 2017.

	December 31,
Changes in pension plan assets	2017			2016
Plan assets at the beginning of year	Ps.	9,489,666		Ps.	5,228,909
Return on plan assets		902,550			742,477
Payments by the pension fund		(54,312,270	)		(51,889,821	)
Company contributions to the fund(1)		51,952,559			55,693,256
Actuarial (gains) losses in plan assets		453,187			(285,155	)
Pension plan assets at the end of year	Ps.	8,485,692		Ps.	9,489,666

⁽¹⁾  Includes proceeds from the collected amounts of the Promissory Notes, contributed by the Mexican Government (See Note 14).

PEMEX’s plan assets are held in two trusts, the FOLAPE and the Fideicomiso de Cobertura Laboral y de Vivienda (FICOLAVI), which are managed by BBVA Bancomer, S. A. and a technical committee for each trust that is comprised of personnel from Petróleos Mexicanos and the trusts.

The expected contribution to the fund for 2018 amounts to Ps. 63,500,000 and the expected payments for 2018 is Ps. 62,337,560.

As of December 31, 2017 and 2016, the amounts and types of plan assets are as follows:

	December 31,
Plan Assets	2017		2016
Cash and cash equivalents	Ps.	135,757	Ps.	5,906,660
Equity instruments		1,034,178		2,694,291
Debt instruments		7,315,757		888,715
Total plan assets	Ps.	8,485,692	Ps.	9,489,666

	December 31,
Changes in Defined Benefit Obligations (DBO)	2017			2016
Defined benefit obligations at the beginning of the year	Ps.	1,212,114,331		Ps.	1,263,708,928
Service costs		19,762,661			23,107,851
Financing costs		96,331,015			91,270,383
Past service costs					(33,244	)
Payments by the fund		(59,417,940	)		(56,778,359	)
Amount of (gains) and losses recognized through other comprehensive income:		(12,594,541	)		(108,589,515	)
Modifications to the pension plan		(6,609,657	)		(571,713	)
Remeasurements		(1,471	)		—
Reductions		(26,399	)		—
Defined benefit obligations at the end of year	Ps.	1,249,557,999		Ps.	1,212,114,331

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The asset ceiling test was not applied because there was a deficit of labor liabilities at the beginning and end of the year.

The effect of an increase or decrease of one percentage point in the discount rate is a -12.46% increase or a 15.72% decrease in defined benefit obligations.

The effect of an increase or decrease of one percentage point in the increase rate in medical services with respect to the cost and obligations related to medical services point is a 21.93% increase or a -16.80% decrease in defined benefit obligations.

Assumptions regarding future mortality are based on EMSSA2009 to Unique Circular of the Comisión Nacional de Seguros y Fianzas (National Commission of Insurance and Bonds) and include changes to the mortality rate established in 2017.

The following tables present additional fair value disclosure about plan assets and indicate their rank, in accordance with IFRS 13, as of December 31, 2017 and 2016:

	Fair value measurements as of December 31, 2017
Plan assets	Quoted prices in active markets for identical assets (level 1)		Significant observable inputs (level 2)		Significant unobservable inputs (level 3)		Total
Cash and cash equivalents	Ps.	135,757	Ps.	—	Ps.	—	Ps.	135,757
Equity instruments		1,034,178		—		—		1,034,178
Debt instruments		7,315,757		—		—		7,315,757
Total	Ps.	8,485,692	Ps.	—	Ps.	—	Ps.	8,485,692

	Fair value measurements as of December 31, 2016
Plan assets:	Quoted prices in active markets for identical assets (level 1)		Significant observable inputs (level 2)		Significant unobservable inputs (level 3)		Total
Cash and cash equivalents	Ps.	5,906,660	Ps.	—	Ps.	—	Ps.	5,906,660
Equity instruments		2,694,291		—		—		2,694,291
Debt instruments		888,715		—		—		888,715
Total	Ps.	9,489,666	Ps.	—	Ps.	—	Ps.	9,489,666

F-108

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

As of December 31, 2017 and 2016, the principal actuarial assumptions used in determining the defined benefit obligation for the plans are as follows:

	December 31,
	2017			2016
Rate of increase in salaries		4.77	%		4.77	%
Rate of increase in pensions		3.75	%		3.75	%
Rate of increase in medical services		7.65	%		7.65	%
Inflation assumption		3.75	%		3.75	%
Discount and return on plan assets rate		7.89	%		8.17	%
Average length of obligation (years)		18.40			17.67

In accordance with IAS 19, the discount rate used is determined by considering the government zero coupon curve generated from the fixed rate bonds issued by the Mexican Government (“Bonds M”) and Cetes, as well as the flow of payments expected to cover contingent liabilities.

Other long-term benefits

Petróleos Mexicanos and Subsidiary Entities has established other long-term benefit plans for its employees, to which employees do not contribute, which correspond to the seniority premiums payable for disability, death and survivors benefits (payable to the widow and beneficiaries of worker), medical service, gas and basic basket for beneficiaries. Benefits under these plans are based on an employee’s salary and years of service completed at separation date. Obligations and costs of such plans are recorded in accordance with actuarial valuations performed by independent actuaries.

The amounts recognized for long-term obligations for the years ended December 31, 2017 and 2016 are as follows:

	December 31,
Change in the liability for defined benefits	2017			2016
Liabilities defined benefit at the beginning of year	Ps.	17,784,771		Ps.	20,905,422
Charge to income for the year		3,277,847			3,420,158
Actuarial (gains) losses recognized in income due to:
Change in financial assumptions		878,516			(3,028,211	)
Change in demographic assumptions		(1,015,274	)		(119,982	)
For experience during the year		(3,558,599	)		(3,390,396	)
Benefits paid		(3,446	)		(2,220	)
Liabilities defined benefit at the end of year	Ps.	17,363,815		Ps.	17,784,771

F-109

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The principal actuarial assumptions used in determining the defined benefit obligation for the plans are as follows:

	December 31,
	2017			2016
Rate of increase in salaries		4.77	%		4.77	%
Inflation assumption		3.75	%		3.75	%
Discount and return on plan assets rate		7.89	%		8.17	%
Average length of obligation (years)		18.40			17.67

In accordance with IAS 19, the discount rate used is determined by considering the government zero coupon curve generated from Bonds M and Cetes, as well as the flow of payments expected to cover contingent liabilities.

NOTE 18. PROVISIONS FOR SUNDRY CREDITORS

At December 31, 2017 and 2016, the provisions for sundry creditors and others is as follows:

	2017		2016
Provision for plugging of wells (Note 12)	Ps.	68,797,600	Ps.	64,967,710
Provision for trails in process (Note 25)		7,812,689		15,119,692
Provision for environmental costs		11,067,134		8,230,476
	Ps.	87,677,423	Ps.	88,317,878

The following tables show the allowance account for plugging of wells, trials in progress and environmental costs:

	Plugging of wells
	2017			2016
Balance at the beginning of the year	Ps.	64,967,710		Ps.	56,894,695
Decrease capitalized in fixed assets		(3,791,482	)		(3,878,503	)
Unwinding of discount against income		7,774,000			11,968,966
Amount used		(152,628	)		(17,448	)
Balance at the end of the year	Ps.	68,797,600		Ps.	64,967,710

	Trials in progress
	2017			2016
Balance at the beginning of the year	Ps.	15,119,692		Ps.	12,775,263
Additions against income		2,835,357			3,049,202
Provision cancellation		(1,973,153	)		(632,806	)
Amount used		(8,169,207	)		(71,967	)
Balance at the end of the year	Ps.	7,812,689		Ps.	15,119,692

F-110

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

	Environmental costs
	2017			2016
Balance at the beginning of the year	Ps.	8,230,476		Ps.	3,521,838
Additions against income		3,203,982			6,118,454
Provision cancellation		(312,937	)		(1,347,285	)
Amount used		(54,387	)		(62,531	)
Balance at the end of the year(1)	Ps.	11,067,134		Ps.	8,230,476

(1) PEMEX is subject to the provisions of the Ley General del Equilibrio Ecológico y la Protección al Ambiente (General Law on Ecological Equilibrium and Environmental Protection). To comply with this law, environmental audits of PEMEX’s larger operating, storage and transportation facilities have been or are being conducted. Following the completion of such audits, PEMEX has signed various agreements with the Procuraduría Federal de Protección al Ambiente (Federal Attorney of Environmental Protection) to implement environmental remediation and improve environmental plans. Such plans contemplate remediation for environmental damages, as well as related investments for the improvement of equipment, maintenance, labor and materials.

Provision for plugging of wells

PEMEX records a provision at present value for the future plugging cost of an oil production facility or pipeline at the time that it is built. Present value is determined based on discount rates ranging from 4.0% to 10.5% in 2017.

The plugging provision represents the present value of plugging costs related to oil and gas properties. These provisions have been created based on internal estimates of PEMEX. PEMEX has made certain assumptions based on the current economic environment that PEMEX believes provide a reasonable basis on which to estimate the future liability. These estimates are reviewed regularly to take into account any material changes in the assumptions. However, actual plugging costs in the long run will depend on future market prices for the necessary plugging work, which reflect market conditions at the time the work is being performed.

Moreover, the time of plugging depends on when the fields cease to have economically viable production rates, which, in turn, depends on the inherently uncertain future prices of oil and gas.

NOTE 19. DISCLOSURES OF CASH FLOW

The following items represent non-cash transactions and are presented for disclosure purposes:

	For the years ended December 31,
	2017			2016		2015
Operating activities
Employee benefits equity effect(i)		Ps. 12,038,710			Ps. 106,277,761		Ps. 78,556,569
Net (benefits) cost of the year for employee benefits(i)		108,073,074			109,738,416		(62,549,142	)
Investing activities(ii)
Available-for-sale financial assets		5,564,130			207,817		(3,206,316	)
Financing activities
Financed Public Works Contracts		—			146,217,292		2,001,093
Currency translation effect		(7,597,283	)		21,386,902		13,262,101
Accrued interest		8,734,131			9,326,945		4,816,784

F-111

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

(i) Items that do not impact cash flows but that reflect the actuarial valuation at the end of the year.

(ii) Non-cash investing transactions are included in Note 12-d.

Material changes in liabilities from financing activities are disclosed in Note 15.

NOTE 20. INCOME TAXES AND FEDERAL DUTIES

The Ley de Ingresos sobre Hidrocarburos (“Hydrocarbons Revenue Law”) was published in the Official Gazette of the Federation on August 11, 2014, and came into effect, on January 1, 2015. The Hydrocarbons Revenue Law sets forth the new fiscal regime for Petróleos Mexicanos applicable to the assignments and the contracts that were established on such date. Likewise, every year the Federal Revenue Law is published in the Official Gazette of the Federation and includes specific regulations for Petroleos Mexicanos and the Subsidiary Entities.

Tax regime applicable to Assignments

The tax regime applicable to the exploration and production for the assignments granted to PEMEX by the Mexican Government includes the following taxes and duties:

a. Derecho por la Utilidad Compartida “DUC” (Profit-sharing Duty).

As of January 1, 2015, Pemex Exploration and Production is obligated to pay a Profit-sharing Duty.

As of January 1, 2017 and 2016, the applicable rate of this duty was 67.50% and 68.75% respectively. The computation of this duty is based on the excess of the value of hydrocarbons produced during the fiscal year (including self-consumption, shrinkage and burning), minus certain permitted deductions by the Hydrocarbons Revenue Law, including part of the investments and some costs, expenses and duties. Pursuant to the Hydrocarbons Revenue Law, this duty decreases on an annual basis. As of January 1, 2019, this duty will be set at 65%.

During 2017, this duty totaled Ps. 372,902,629 from annual payments presented on March 31, 2018 paid as follows: Ps. 377,192,377, in monthly installment payments and a favorable balance amounting to Ps. 4,289,748, presented in accounts receivable, net line item in the statement of financial position.

During 2016, this duty totaled Ps. 304,299,019 from annual payments presented on April 3, 2017 paid as follows: Ps. 301,050,325, in monthly installment payments and a payable balance amounting to Ps. 3,248,694.

The accounting result differs from the tax result mainly due to differences in depreciation, non-deductible expenses and others. Such differences generate a deferred DUC.

Total DUC and other as of December 31, 2017 and 2016 are integrated as follows:

	2017			2016
DUC	Ps.	372,902,629		Ps.	304,299,019
DUC from prior years		2,095,429			—
Other		260,775			514,356
Deferred DUC benefit		(37,214,624	)		(27,651,571	)
Total DUC and other	Ps.	338,044,209		Ps.	277,161,804

F-112

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The principal factors generating the deferred DUC are the following:

	2017			2016
Deferred DUC asset:
Provisions	Ps.	541,360,940		Ps.	570,544,863
Total deferred DUC asset		541,360,940			570,544,863
Deferred Profit-sharing duty liability:
Wells, pipelines, properties, plant and equipment		(455,697,786	)		(473,406,721	)
Deferred DUC liability		(455,697,786	)		(473,406,721	)
Deferred asset net		85,663,154			97,138,142
Valuation reserve(1)		(20,796,959	)		(69,486,571	)
Net, deferred DUC asset	Ps.	64,866,195		Ps.	27,651,571
(1)   PEMEX added to its valuation reserve since it estimates that some allowed deductions will not materialize in future years.

The expected expense for DUC is different from that which would result from applying the 65% rate to the tax base, as a result of the items mentioned below:

	2017			2016
Expected expense:		Ps. 127,436,912			Ps. 159,897,683
Increase (decrease) resulting from:
Non-cumulative profit		(514,780,219	)		(423,761,673	)
Non-deductible expenses		387,343,306			263,863,990
Production value		518,433,469			441,655,000
Deductible duties		(39,503,110	)		(29,918,201	)
Deferred DUC reserve		(48,689,612	)		69,486,571
Deductions cap		(94,552,741	)		(204,575,922	)
DUC from prior years		2,095,429			—
Other		260,775			514,356
DUC-Profit-sharing duty expense		Ps. 338,044,209			Ps. 277,161,804

On August 18, 2017, the Official Gazette of the Federation published a decree, granting tax benefits for extraction activities in assignments with mature and / or marginal fields, substantially increasing the percentage of costs, expenses and investments that PEMEX could deduct for purposes of calculating the DUC. As a result, PEMEX received a tax benefit of Ps. 7,769,915.

On November 30, 2017, the Acuerdo por el que se reforman y adicionan diversas disposiciones de las Reglas de carácter general para definir los métodos de ajuste del valor de los hidrocarburos de los derechos sobre hidrocarburos (Agreement by which various provisions of the general rules are reformed and added to define the methods of adjusting the value of hydrocarbons and hydrocarbon rights)was published in the Official

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Gazette of the Federation, resulting in new calibrations and adjustments of existing formulas of calculating the value of hydrocarbons and hydrocarbon rights. As a result, PEMEX received an estimated tax benefit of Ps. 8,854,391.

The compensation of Ps. 2,186,963 was also authorized for the recognition of the fair economic value of the investments affected as a result of the allocation process for assignments to carry out hydrocarbon exploration and extraction activities, in accordance with the provisions of Transitory Article 21 of the Federation Income Law of 2017.

On April 18, 2016, a decree granting a fiscal benefit to Pemex Exploration and Production (assignee) was published in the Official Gazette of the Federation and increases the limit on the amount Pemex Exploration and Production can deduct for costs, expenses and investments in the calculation of its DUC, for onshore areas or in offshore areas with water depths lower than 500 meters. The benefit was granted to further the Mexican Government’s strategic hydrocarbon exploration and extraction activities through assignments, in light of historically low international hydrocarbons prices in late 2015 and early 2016 combined with historically low oil production in Mexico, thereby, together with other actions avoiding that the worldwide economic conditions had affected the national economy. The benefit obtained was Ps. 40,213,913. Additionally, the Mexican Government granted PEMEX a fiscal support on November 16, 2016 of Ps. 28,439,379. This benefit consisted of a tax credit against the DUC as a measure to mitigate the impact generated by the financial environment of the Mexican hydrocarbons exploration and extraction companies (assignees), as international energy prices continued to be depressed, which impacted the economies of several countries, including Mexico.

b. Derecho de Extracción de Hidrocarburos (Hydrocarbons Extraction Duty).

This duty is to be calculated using a rate based on a formula applicable to each type of hydrocarbon, the volume of production and utilizing the relevant market price for hydrocarbons in U.S. Dollars.

During 2017 Pemex Exploration and Production made payments of Ps. 58,523,125, which are included in the cost of sales line item.

c. Derecho de Exploración de Hidrocarburos (Exploration Hydrocarbons Duty).

The Mexican Government is entitled to collect a monthly payment of Ps. 1,214.21 per square kilometer of non-producing areas. After 60 months, this tax increases to Ps. 2,903.54 per square kilometer for each additional month that the area is not producing. These amounts will be updated on an annual basis in accordance with the national consumer price index.

During 2017, Pemex Exploration and Production made payments under this duty, totaling Ps. 980,843, which are included in the cost of sales line item.

d. Impuesto por la actividad de Exploración y Extracción de Hidrocarburos (Exploration and Extraction Hydrocarbons Duty).

The assignments granted by the Mexican Government create a tax on the exploration and extraction activities carried out in the corresponding area. The monthly tax paid during the exploration phase and until the extraction phase begins is Ps. 1,583.74 per square kilometer. During the extraction phase, the monthly tax from the start of the extraction phase and until the assignment ends is Ps. 6,334.98 per square kilometer. During 2017 payments for this tax amounted Ps. 3,986,112, which are included in the cost of sales line item.

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Tax Regime applicable to contracts:

As of January 1, 2015, the tax regime applicable to Pemex Exploration and Production for contracts is set forth in the Hydrocarbons Revenue law which regulates, among other things, the fiscal terms applicable to the exploration and extraction contracts (license, profit sharing contracts, production sharing and services) and sets duties and other taxes paid to the Mexican Government.

The Hydrocarbons Revenue Law also establishes the following duties applicable to PEMEX in connection with assignments granted to it by the Mexican Government:

• Cuota Contractual para la Fase Exploratoria (Exploration Phase Contractual Fee)

During the exploration phase of an exploration and extraction contract, the Mexican Government is entitled to collect a monthly payment of Ps. 1,175.42 per square kilometer of non-producing areas. After 60 months, this fee increases to Ps. 2,810.78 per square kilometer for each additional month that the area is not producing. The fee amount will be updated on an annual basis in accordance with the national consumer price index.

• Regalías (Royalties)

Royalty payments to the Mexican Government are determined based on the “contractual value” of the relevant hydrocarbons, which is based on a variety of factors, including the type of underlying hydrocarbons (e.g., crude oil, associated natural gas, non-associated natural gas or condensates), the volume of production and the market price. Royalties are payable in connection with licensing contracts, production-sharing contracts and profit-sharing contracts.

• Pago del Valor Contractual (Contractual Value Payment)

Licensing contracts require a payment to the Mexican Government calculated as a percentage of the “contractual value” of the hydrocarbons produced, as determined by the SHCP on a contract-by-contract basis.

• Porcentaje a la Utilidad Operativa (Operating Profit Payment)

Production-sharing contracts and profit-sharing contracts require a payment equivalent to a specified percentage of operating profits. In the case of production-sharing contracts, this payment shall be made in-kind through delivery of the hydrocarbons produced. In the case of profit-sharing contracts, this payment shall be made in cash.

• Bono a la Firma (Signing Bonus)

Upon execution of a licensing contract, a signing bonus is to be paid to the Mexican Government in an amount specified by the SHCP in the relevant bidding terms and conditions or in the contracts resulting from a migration.

• Impuesto por la actividad de Exploración y Extracción de Hidrocarburos (Hydrocarbons Exploration and Extraction Activities Tax)

Contracts for exploration and extraction granted by the Mexican Government will include a specified tax on the exploration and extraction activities carried out in the relevant area. A monthly tax of Ps. 1,583.74 per square kilometer is payable during the exploration phase until the extraction phase begins. During the extraction phase of a project, a monthly tax of Ps. 6,334.98 per square kilometer is payable from the starting date until the relevant contract for exploration and extraction is terminated.

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Other applicable taxes

Beginning with the creation of the Subsidiary Entities during 2015, they became subject to the Income Tax Law and the Value Added Tax Law. Pemex Industrial Transformation is also subject to the Special Tax on Production and Services (IEPS Tax).

2017 indirect taxes are as listed below:

a. IEPS Tax

IEPS Tax on the sale of automotive fuels: This is a tax imposed on domestic sales of automotive fuels, including gasoline and diesel, which Pemex Industrial Transformation collects on behalf of the Mexican Government. The applicable quotas for 2017 were: 4.30 pesos per liter of Magna gasoline; 3.64 pesos per liter of Premium gasoline and 4.73 pesos per liter of diesel. This fee is updated annually according to inflation and adjusted monthly by the tax authorities.

IEPS Tax to benefit Mexican states and municipalities: This tax is a quota on domestic sales of automotive fuels, including gasoline and diesel, which Pemex Industrial Transformation collects on behalf of the Mexican Government. The applicable quotas for 2017 were 38.00 cents per liter of Magna gasoline, 46.37 cents per liter of premium gasoline and 31.54 cents per liter of diesel. This rate is updated annually with inflation. The funds raised by this quota are allocated to the states and municipalities as provided in the Tax Coordination Law.

IEPS Tax on Fossil Fuels: This tax is a quota on the internal sales of fossil fuels, which Pemex Industrial Transformation collects on behalf of the Mexican Government. The applicable quotas for 2017 were 6.50 cents per liter for propane, 8.42 cents per liter for butane, 11.41 cents per liter for jet and other fuel, 13.64 cents per liter for turbosine and other kerosene, 13.84 cents per liter for diesel, 14.78 cents per liter for fuel oil and Ps. 17.15 per ton for petroleum coke. This rate is updated annually according to inflation.

b. Value Added Tax (“VAT”)

For VAT purposes, final monthly payments are determined based on PEMEX’s cash flow, in accordance with the provisions of the Value Added Tax Law, applicable to payers of this tax.

The VAT is caused by the sales of goods, rendering of services, granting of the temporary use of goods in the national territory and by the importation of goods and services to the national territory. VAT taxpayers transfer VAT to their customers and are entitled to credit the VAT paid to their suppliers and on their imports. The net balance between VAT transferred to customers and paid to suppliers and on imports results each month in the VAT to be paid to the tax authorities or in an amount in favor of the taxpayer. The taxpayer has the right to credit VAT in favor against VAT payable in future months, to request a refund or to offset it against other payable federal taxes.

Taxes on Income are described below:

c. Income Tax

As of January 1, 2015, Petróleos Mexicanos, Subsidiary Entities and the subsidiary companies residing in Mexico for tax purposes are subject to the Income Tax Law.

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

This tax is calculated by applying a rate of 30% to the tax result. Tax result is the excess of total revenues over the allowed deductions and tax losses from previous years.

Accounting income differs from taxable income primarily due to the effects of inflation and differences between depreciation and other non-deductible expenses.

For the years ended December 31, 2017, 2016 and 2015, Petroleos Mexicanos and its Subsidiary Companies incurred the following income tax expense (benefit):

	2017			2016			2015
Current income tax	Ps.	3,546,912		Ps.	6,201,842		Ps.	7,426,892
Deferred income tax		(9,334,064	)		(18,842,211	)		(53,014,159	)
Total	Ps.	(5,787,152	)	Ps.	(12,640,369	)	Ps.	(45,587,267	)
Income tax REFIPRE (Preferent Fiscal Regime)	Ps.	722,984		Ps.	—		Ps.	—

The principal factors generating the deferred income tax are the following:

	2016			Recognized in profit and loss			Recognized in OCI			2017
Deferred income tax asset:
Provisions	Ps.	5,906,581		Ps.	2,393,237		Ps.	—		Ps.	8,299,818
Employee benefits provision		125,973,332			4,902,275			(800,284	)		130,075,323
Advance payments from clients		1,046,010			1,728,296			—			2,774,306
Accrued liabilities		2,269,561			(1,897,574	)		—			371,987
Non-recoverable accounts receivable		778,179			(38,431	)		—			739,748
Derivative financial instruments		223,518			(144,263	)		—			79,255
Wells, pipelines, properties and equipment		458,273,897			(52,834,079	)		—			405,439,818
Tax loss carryforwards(1)		43,327,737			(9,216,777	)		—			34,110,960
Total deferred income tax asset		637,798,815			(55,107,316	)		(800,284	)		581,891,215
Valuation reserve(2)		(565,125,697	)		64,560,772			—			(500,564,925	)
Net deferred income tax asset		72,673,118			9,453,456			(800,284	)		81,326,290
Deferred income tax liability:
Wells, pipelines, properties, plant and equipment		(3,632,294	)		188,676			—			(3,443,618	)
Other		(502,242	)		(308,068	)		—			(810,310	)
Total deferred income tax liability		(4,134,536	)		(119,392	)		—			(4,253,928	)
Net long-term deferred income tax liability	Ps.	68,538,582		Ps.	9,334,064		Ps.	(800,284	)	Ps.	77,072,362

F-117

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

	2015			Recognized in profit and loss			Recognized in OCI and equity (3)			2016
Deferred income tax asset:
Provisions	Ps.	25,414,822		Ps.	(19,508,241	)	Ps.	—		Ps.	5,906,581
Employee benefits provision		247,834,882			(119,837,137	)		(2,024,413	)		125,973,332
Advance payments from clients		1,015,357			30,653			—			1,046,010
Accrued liabilities		1,514			2,268,047			—			2,269,561
Non-recoverable accounts receivable		104,346			673,833			—			778,179
Derivative financial instruments		22,506			201,012			—			223,518
Wells, pipelines, properties and equipment		446,970,333			11,303,564			—			458,273,897
Tax loss carryforwards(1)		14,894,231			28,433,506			—			43,327,737
Total deferred income tax asset		736,257,991			(96,434,763	)		(2,024,413	)		637,798,815
Valuation reserve(2)		(681,357,607	)		116,231,910			—			(565,125,697	)
Net deferred income tax asset		54,900,384			19,797,147			(2,024,413	)		72,673,118
Deferred income tax liability:
Wells, pipelines, properties, plant and equipment		(1,909,529	)		(726,999	)		(995,766	)		(3,632,294	)
Other		(274,305	)		(227,937	)		—			(502,242	)
Total deferred income tax liability		(2,183,834	)		(954,936	)		(995,766	)		(4,134,536	)
Net long-term deferred income tax liability	Ps.	52,716,550		Ps.	18,842,211		Ps.	(3,020,179	)	Ps.	68,538,582

(1) Tax loss carryforwards expire in 2027.

(2) Due to PEMEX’s estimate that not enough taxable income will be generated in future periods, a valuation reserve was recognized to account for the deferred income tax asset.

(3) Includes effects from business combination in equity of Ps. (995,766).

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Expense attributable to the profit (loss) from continuing operations before income taxes was different from that which would result from applying the 30% rate to profit, as a result of the items listed below:

	For the years ended December 31,
	2017			2016			2015
Expected income tax expense	Ps.	(20,055,588	)	Ps.	(14,901,324	)	Ps.	(3,089,241	)
Increase (decrease) resulting from:
Tax effect of inflation-net		14,302,118			8,098,213			(1,618,327	)
Difference between accounting and tax depreciation		(3,713,920	)		(1,765,183	)		(107,231	)
Non-deductible expenses		1,954,659			1,558,120			(1,921,515	)
Others-net		(1,725,579	)		(5,630,195	)		(38,850,953	)
Income tax expense	Ps.	(5,787,152	)	Ps.	(12,640,369	)	Ps.	(45,587,267	)

As of December 31, 2017 and 2016, the net accumulated effect of actuarial gains and losses on deferred tax was Ps. 17,688,032 and Ps. 16,887,748, respectively. In addition, as of December 31, 2017 and 2016, the deferred tax effect of actuarial gains and losses from Petróleos Mexicanos and PMI CIM are presented in comprehensive (loss) income in the amounts of Ps. (800,284) and Ps. (2,024,413), respectively. As of December 31, 2015, the deferred tax effect of PMI CIM’s performance was Ps. (124,285).

NOTE 21. EQUITY (DEFICIT), NET

a. Certificates of Contribution “A”

The capitalization agreement between Petróleos Mexicanos and the Mexican Government states that the Certificates of Contribution “A” constitute permanent capital.

On January 19, 2015, the Mexican Government made an equity contribution of Ps. 10,000,000 to Petróleos Mexicanos in accordance with the Ley Federal del Presupuesto y Responsabilidad Hacendaria (Federal Law of Budget and Fiscal Accountability).

On December 24, 2015, the Mexican Government, through the SHCP, issued a non-negotiable promissory note of Ps. 50,000,000 due December 31, 2050 for the assumption by the Mexican Government of the payment obligations related to pensions and retirement plans of Petróleos Mexicanos and its Subsidiary Entities (see Note 14).

On April 21, 2016, the Mexican Government made an equity contribution to Petróleos Mexicanos in the amount of Ps. 26,500,000 following the guidelines established in the Federal Budget and Fiscal Responsibility. This contribution was recognized as an increase in Certificates of Contribution “A.”

On August 3, 2016, the Mexican Government issued Ps. 184,230,586 in exchange for the Ps. 50,000,000 non-negotiable promissory note issued to Petróleos Mexicanos on December 24, 2015, which was recognized as a Ps. 135,439,612 increase in equity. The Ps. 135,439,612 increase in equity was the result of the Ps. 184,230,586 value of the promissory notes as of June 29, 2016, minus the Ps. 50,000,000 promissory note received by

F-119

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Petróleos Mexicanos on December 24, 2015, plus a Ps. 1,209,026 increase in the value of the promissory notes from June 29, 2016 to August 15, 2016, the date on which Petróleos Mexicanos received the promissory notes (see Note 14).

PEMEX’s permanent equity is as follows:

	Amount
Certificates of Contribution “A” as of December 31, 2015	Ps.	194,604,835
Increase in Certificates of Contribution “A” during 2016		161,939,612
Certificates of Contribution “A” as of December 31, 2016		356,544,447
Increase in Certificates of Contribution “A” during 2017		—
Certificates of Contribution “A” as of December 31, 2017	Ps.	356,544,447

b. Mexican Government contributions

As of December 31, 2017 and 2016 there were no Mexican Government contributions.

c. Legal reserve

Under Mexican law, each of the Subsidiary Companies is required to allocate a certain percentage of its net income to a legal reserve fund until the fund reaches an amount equal to a certain percentage of each Subsidiary Company’s capital stock.

As of December 31, 2017 and 2016, there were no changes to the legal reserve.

d. Accumulated deficit from prior years

PEMEX has recorded negative earnings in the past several years. However, the Ley de Concursos Mercantiles (“Commercial Bankruptcy Law of Mexico”) is not applicable to Petróleos Mexicanos and the Subsidiary Entities. Furthermore, the financing agreements to which PEMEX is a party do not provide for financial covenants that would be breached or events of default that would be triggered as a consequence of negative equity (see Note 2-b). The Mexican Government has focused its recent efforts on consolidating PEMEX’s institutional strategy, including the approval of amendments to the Mexican Constitution published as the Energy Reform Decree on December 20, 2013, which permit it greater autonomy in decision-making and enhanced operational viability (see Note 1).

e. Non-controlling interest

Effective July 1, 2005, PEMEX entered into an option agreement with BNP Private Bank & Trust Cayman Limited; the option was not exercised and was terminated on July 20, 2015. On July 1, 2015, PEMEX also entered into a new option agreement with SML Trustees Limited to acquire 100% of the shares of Pemex Finance, Ltd, which allows PEMEX to have control over Pemex Finance Ltd. because of the potential voting rights. As of the date of these consolidated financial statements the option agreement has not been exercised. As a result, the financial results of Pemex Finance, Ltd. are included in these consolidated financial statements of PEMEX. Under IFRS, variations in income and equity from Pemex Finance, Ltd. are presented in the

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

consolidated statements of changes in equity (deficit), net as “non-controlling interest,” and as net income and comprehensive income for the year, attributable to non-controlling interest, in the consolidated statements of comprehensive income, due to the fact that PEMEX does not currently own any of the shares of Pemex Finance, Ltd.

Similarly, because PEMEX does not currently own all of the shares of PMI CIM, HJ BARRERAS and COMESA, variations in income and equity from these entities are also presented in the consolidated statements of changes in equity (deficit) as “non-controlling interest.”

As of December 31, 2017 and 2016, non-controlling interest represented gains of Ps. 965,107 and Ps. 976,705, respectively, in PEMEX’s equity (deficit).

NOTE 22. OTHER REVENUES AND EXPENSES-NET

Other revenues and expenses-net for each of the years ended December 31, 2017, 2016 and 2015, was as follows:

	2017			2016			2015
Revenues:
Claims recovery	Ps.	16,386,250		Ps.	3,695,217		Ps.	1,975,281
Fiscal support (Profit-sharing duty) (see Note 20a.)		—			28,439,379			—
Other income for services		4,720,546			4,266,854			3,953,888
Price of sale share (see Note 11-iii)		3,139,103			22,684,736			—
Other		4,277,207			14,228,801			6,992,954
Revenues from reinsurance premiums		1,986,568			3,694,026			1,497,779
Franchise fees		917,934			1,059,333			1,148,528
Bidding terms, sanctions, penalties and other		825,956			3,223,437			1,262,458
Gain on sale of fixed assets		—			2,687,652			—
Assets value transferred to CENAGAS		—			7,450,931			—
Negative IEPS		—			—			2,519,126
Total other revenues		32,253,564			91,430,366			19,350,014
Expenses:
Loss in the Assets value transferred to CENAGAS		—			(35,333,411	)		—
Disposal of assets		(8,447,031	)		(2,140,943	)		(3,364,063	)
Transportation and distribution of natural gas		(6,652,878	)		(8,830,967	)		(369,317	)
Other		(7,927,150	)		(3,581,036	)		(726,589	)
Claims		(3,640,036	)		(4,757,116	)		(12,527,548	)
Loss in the sale of associates		(412,393	)		(7,473,698	)		—
Impairment of goodwill		—			(4,007,018	)		—
Services provided		—			(2,656,571	)		(3,237,984	)
Total other expenses		(27,079,488	)		(68,780,760	)		(20,225,501	)
Other revenues and expenses-net	Ps.	5,174,076		Ps.	22,649,606		Ps.	(875,487	)

F-121

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

NOTE 23. RELATED PARTIES

Directors and employees of Petróleos Mexicanos and the Subsidiary Entities are subject to regulations related conflict of interest such as the Petróleos Mexicanos Law, Ley Federal de Responsabilidades Administrativas de los Servidores Públicos (Federal Law of Administrative Responsibilities of Public Officials) and the Políticas y Lineamientos Anticorrupción para Petróleos Mexicanos, sus Empresas Productivas Subsidiarias y, en su caso, Empresas Filiales (Anticorruption Policies and Guidelines for Petróleos Mexicanos, its Subsidiary Productive Companies and, where applicable, Subsidiary Companies). Under these provisions, PEMEX’s directors and employees are obligated to “recuse themselves from intervening in any way in the attention to, processing or resolution of matters in which they might have personal, family or business interest, including those where some benefit can result for themselves, their spouse, blood or affinity relatives up to the fourth degree, or civil relatives, or for third parties with which they have professional, labor or business relations, or for partners or partnerships where the public officials or the persons referred above are or have been members thereof.”

Related parties include individuals and companies that do not form part of PEMEX, but that could take advantage of being in a privileged position as a result of their relation with PEMEX. Also included are situations in which PEMEX could take advantage of a special relationship in order to benefit its financial position or results of operations.

F-122

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Secretary of Energy, Mr. Pedro Joaquín Coldwell, Chairman of the Board of Directors of Petróleos Mexicanos since December 2012, as well as certain members of his family, have held ownership interests since prior to Mr. Pedro Joaquín Coldwell’s appointment to the Board of Directors and through October of 2017 in companies that have entered into agreements with Pemex-Refining, which are now obligations of Pemex Industrial Transformation, for the sale and purchase of gasoline and other products by certain retail service stations and a wholesale distributor, as well as the performance of other related activities, as provided below:

Company	Name	Ownership share
Servicio Cozumel, S. A. de C. V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1)		60	%
	Mr. Pedro Oscar Joaquín Delbouis (son of Mr. Joaquín Coldwell)		20	%
	Mr. Nassim Joaquín Delbouis (son of Mr. Joaquín Coldwell)		20	%
Planta de Combustible Cozumel, S. A. de C. V. (which operates as a wholesale distributor)	Fideicomiso Testamentario(2)		57	%
	Mr. Pedro Joaquín Coldwell(1)		40	%
Gasolinera y Servicios Juárez, S. A. de C. V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1)		40	%
	Fideicomiso Testamentario(3)		40	%
	Mr. Ignacio Nassim Ruiz Joaquín (nephew of Mr. Joaquín Coldwell)		20	%
Combustibles Caleta, S. A. de C. V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1)		20	%
	Mr. Pedro Oscar Joaquín Delbouis		20	%
	Mr. Nassim Joaquín Delbouis		20	%
	Fideicomiso Testamentario(4)		20	%
	Mr. Ignacio Nassim Ruiz Joaquín		20	%
Combustibles San Miguel, S. A. de C. V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1)		25	%
	Mr. Pedro Oscar Joaquín Delbouis		25	%
	Mr. Nassim Joaquín Delbouis		25	%
	Mr. Ignacio Nassim Ruiz Joaquín		25	%

(1) In November, 2017, Mr. Pedro Joaquín Coldwell transmitted all of his shares in these companies to a management and investment trust held at Banco Mercantil del Norte, S.A., Institución de Banca Múltiple, Grupo Financiero Banorte.

(2) 60% of these shares were owned by Fausto Nassim Joaquín Ibarra (father of Pedro Joaquín Coldwell), until his death in June of 2016, after which 57% of these shares became property of an investment, management and testamentary revocable trust, which is referred to as the Testamentary Trust. 50% of the voting rights of these shares are currently exercised by Mr. Pedro Oscar Joaquín Delbouis, and 50% are exercised by Mr. Nassim Joaquín Delbouis.

(3) 40% of these shares were owned by Fausto Nassim Joaquín Ibarra until his death in June of 2016, after which these shares became property of the Testamentary Trust. 100% of the voting rights of these shares are currently exercised by Mr. Pedro Joaquín Coldwell.

(4) 20% of these shares were owned by Fausto Nassim Joaquín Ibarra until his death in June of 2016, after which these shares became property of the Testamentary Trust. 50% of the voting rights of these shares are currently exercised by Mr. Pedro Oscar Joaquín Delbouis, and 50% are exercised by Mr. Nassim Joaquín Delbouis.

F-123

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The rights of these companies to operate retail service stations and distribute gasoline and other products on a wholesale basis in Mexico are dependent on these agreements, the expiration or non-renewal of which may adversely affect their business. These agreements are based on PEMEX’s standard forms of agreements and contain the standard terms and conditions applicable to all of Pemex Industrial Transformation’s retail service stations and wholesale distributors.

a. Compensation of Directors and Officers

For the years ended December 31, 2017, 2016 and 2015, the aggregate compensation of executive officers of Petróleos Mexicanos and the Subsidiary Entities paid or accrued in that year for services in all capacities was approximately Ps. 50,749, Ps. 49,165 and Ps. 116,930, respectively. Retirement and former employee benefits are granted as described in Note 17. Except in the case of the professional members, with respect to the previous Board of Directors of Petróleos Mexicanos and the boards of directors of the existing Subsidiary Entities, and the independent members, with respect to the new Board of Directors of Petróleos Mexicanos, members of the Boards of Directors of Petróleos Mexicanos and the Subsidiary Entities do not receive compensation for their services.

The compensation paid or accrued during 2017, 2016 and 2015 to the professional members of the previous Board of Directors of Petróleos Mexicanos and boards of directors of the existing Subsidiary Entities was approximately Ps. 7,525, Ps. 8,339, and Ps. 17,899, respectively.

b. Salary Advances

As an employee benefit, PEMEX offers salary advances to all of its eligible Petroleum Workers’ Union and non-union workers, including executive officers, pursuant to the programs set forth in the collective bargaining agreement and in the Reglamento de Trabajo del Personal de Confianza de Petróleos Mexicanos y Empresas Productivas Subsidiarias (Employment Regulation of White Collar Employees of Petróleos Mexicanos and Subsidiary Entities), respectively. The salary advances, which are non-interest bearing, are offered to each eligible employee in an amount up to a maximum of four months’ salary and are repaid through salary deductions in equal installments over a period of either one or two years, as elected by the employee. Most employees take advantage of this benefit. The amount of salary advances outstanding to executive officers at December 31, 2017 was Ps. 3,466 and at December 31, 2016 was Ps. 2,415. The amount of salary advances outstanding to executive officers at March 31, 2018 was Ps. 2,363.

NOTE 24. COMMITMENTS

a. PMI CIM has entered into several contracts for the sale of crude oil on the international market to foreign companies. The terms and conditions of these contracts are specific to each client, and their durations may be indefinite (evergreen contracts) or they may contain a minimum obligatory period (long-term contracts).

b. PEMEX has entered into a nitrogen supply contract for the pressure maintenance program at the Cantarell complex. During 2007, an additional contract was entered into with the purpose of supplying nitrogen to the

F-124

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Ku-Maloob-Zap complex and extending the original contract until 2027. At December 31, 2016 and 2015, the value of the nitrogen to be supplied during the term of the contract was approximately Ps. 7,506,619 and Ps. 8,646,726, respectively. In the event of the annulment of the contract and depending on the circumstances, PEMEX has the right or the obligation to acquire the vendor’s nitrogen plant under the terms of the contract.

Estimated future payments under this contract for upcoming fiscal years are as follows:

2018	Ps.	773,047
2019		783,197
2020		785,670
2021		786,323
2022		782,584
2023 and thereafter		3,595,798
Total	Ps.	7,506,619

c. As of December 31, 2017, PEMEX had entered into FPWCs by means of which the contractor manages and is responsible for financing performance of the work to be undertaken.

As of December 31, 2017 and 2016, the estimated value of these contracts was as follows:

Maturity	2017		2016
Up to 1 year	Ps.	5,533,174	Ps.	7,366,247
1 to 3 years		1,891,557		2,518,207
4 to 5 years		1,856,006		2,470,878
More than 5 years		3,123,173		4,157,843
Total	Ps.	12,403,910	Ps.	16,513,175

d. As of December 31, 2017 and 2016, Pemex Exploration and Production, has in operation certain integrated exploration and production contracts (“Integrated E&P Contracts”) for the development of mature fields in the Altamira, Ébano, Nejo, Pánuco and San Andrés blocks in the Northern region of Mexico and Magallanes, Santuario and Carrizo blocks in the Southern region of Mexico, respectively. Each contract has a term of up to 25 years. Payments to the contractors pursuant to the Integrated E&P Contracts will be made on a per-barrel basis, plus recovery of certain costs, provided that the payments to the contractor may not exceed PEMEX’s cash flow from the particular block subject to each contract. During 2017, PEMEX made payments pursuant to the Integrated E&P Contracts in the Northern region of Ps. 6,594,486 and in the Southern region of Ps. 727,331. During 2016, PEMEX made payments pursuant to the Integrated E&P Contracts in the Northern region of Ps. 7,026,822 and in the Southern region of Ps. 524,475. As of December 31, 2017 there is no outstanding liability due to the fact that the available cash flow has an annual maturity and has not yet matured. Additionally, these contracts are in the process of being migrated to a new EEC.

F-125

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

e. As of December 31, 2017 and 2016, the estimated value of the contracts that PEMEX has entered into with several contractors for the development of various infrastructure and services works was as follows:

Maturity	2017		2016
Up to 1 year	Ps.	229,738,368	Ps.	347,606,848
1 to 3 years		196,335,411		281,563,607
4 to 5 years		123,159,215		69,541,826
More than 5 years		149,672,236		119,281,849
Total	Ps.	698,905,230	Ps.	817,994,130

NOTE 25. CONTINGENCIES

In the ordinary course of business, PEMEX is named in a number of lawsuits of various types. PEMEX evaluates the merit of each claim and assesses the likely outcome. PEMEX has not recorded provisions related to ongoing legal proceedings due to the fact that an unfavorable resolution is not expected in such proceedings, with the exception of the proceeding described in further detail in this Note.

PEMEX is involved in various civil, tax, criminal, administrative, labor and commercial lawsuits and arbitration proceedings. The results of these proceedings are uncertain as of the date of these consolidated financial statements. As of December 31, 2017 and 2016, PEMEX had accrued a reserve of Ps. 7,812,689 and Ps. 15,119,692, respectively, for these contingent liabilities. As of December 31, 2017, the current status of the principal lawsuits in which PEMEX is involved is as follows:

• On April 4, 2011, Pemex-Exploration and Production was summoned before the Séptima Sala Regional Metropolitana (“Seventh Regional Metropolitan Court”) of the Tribunal Federal de Justicia Fiscal y Administrativa (“Tax and Administrative Federal Court”) in connection with an administrative claim (No. 4957/1117071) filed by EMS Energy Services de México, S. de R.L. de C.V. and Energy Maintenance Services Group I. LLC requesting that Pemex-Exploration and Production’s termination of the public works contract be declared null and void. In a concurrent proceeding, the plaintiffs also filed an administrative claim (No. 13620/15-17-06) against Pemex Exploration and Production before the Sexta Sala Regional Metropolitana (“Sixth Regional Metropolitan Court”) of the Tax and Administrative Federal Court in Mexico City seeking damages totaling U.S. $193,713 related to the above-mentioned contract. Pemex-Exploration and Production filed a response requesting the two administrative claims be joined in a single proceeding, which was granted on May 10, 2016 by the Seventh Regional Metropolitan Court. On May 3, 2017, the proceeding was closed for a judgment to be issued. As of the date of these financial statements, a resolution from the Second Section of the Superior Court of the Tax and Administrative Federal Court is still pending.

• In June 2016, Pemex Exploration and Production was summoned before the Juzgado Octavo de Distrito en Materia Civil (“Eighth Civil District Court”) in Mexico City, in connection with a claim filed by Drake Mesa, S. de R.L. (file No. 200/2016-II), seeking approximately U.S.$120,856 related to expenses and damages, in connection with a public work agreement executed between them. On November 9, 2017, a judgment was issued finding the Eighth Civil District Court lacked jurisdiction over this case. Both parties filed appeals against this resolution. As of the date of these financial statements, a final resolution is still pending.

• On June 11, 2015, the Segunda Sala Regional del Noreste (“Second Regional Northeast Court”) notified Pemex-Refining of an administrative claim (file no. 2383/15-06-02-4) filed by Severo

F-126

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Granados Mendoza, Luciano Machorro Olvera and Hilario Martínez Cerda, as President, Secretary and Treasurer of the Ejido Tepehuaje, seeking Ps. 2,094,232 in damages due to a hydrocarbon spill on their land. Pemex-Refining filed a response to this claim and the plaintiffs were given time to amend their claim. The defendant filed a motion against this resolution and responded to the amended claim on February 17, 2017. The trial is in the evidentiary stage. The appointment of an independent expert related to environmental issues is still pending. A final judgment is still pending.

• On July 8, 2011, Pemex Exploration and Production was summoned in connection with an administrative claim (no. 4334/1111026) filed by Compañía Petrolera La Norma, S.A., against the Chief Executive Officer of Petróleos Mexicanos and the Chief Executive Officer of Pemex-Exploration and Production before the Segunda Sala Regional Hidalgo-México (“Hidalgo-Mexico Second Regional Court”) of the Tax Administrative Federal Court in Tlalnepantla, Estado de México. The plaintiff is seeking compensation for the cancellation of its alleged petroleum rights concessions and damages for up to Ps.1,552,730. On August 20, 2014, the proceeding was sent to the Segunda Sección de la Sala Superior (“Second Section of The Superior Court”) of the Tax and Administrative Federal Court (4334/11-11-02-6/1337/14-s2-07-04). On October 29, 2014, the proceeding was returned to the Second Regional Court to correct a procedural error. A new term to file pleas was approved. On September 7, 2017, a motion was filed questioning a signature’s authenticity. In December 2017, a documentary expert’s opinion was filed by the plaintiff and a new expert was designated by Pemex Exploration and Production. The acceptance of this designation is still pending. As of the date of these financial statements, a final resolution is still pending.

• On December 12, 2017, Pemex Exploration and Production was summoned in connection with an arbitration claim (no. 23217/JPA) filed by SUBSEA 7 de México, S. de R. L. de C.V. (“SUBSEA 7”) seeking U.S.$153,000 related to additional expenses in connection with a pipelines construction contract. A response by the defendant is still pending as of the date of these financial statements.

• On August 1, 2017, Pemex Exploration and Production was summoned in connection with an administrative claim (no. 11590/17-17-06-2) filed by Proyectos y Cimentaciones Industriales, S.A. de C.V. before the Sixth Regional Metropolitan Court seeking Ps. 800,000 and U.S.$ 12.82 and to have the settlement certificate dated March 22, 2017 related to services agreement declared null and void. On September 25, 2017 Pemex Exploration and Production filed a response to this claim. As of the date of these financial statements, a final resolution is still pending.

The results of these proceedings are uncertain until their final resolutions are issued by the appropriate authorities. PEMEX has recorded liabilities for loss contingencies when it is probable that a liability has been incurred and the amount thereof can be reasonably estimated. When a reasonable estimation could not be made, qualitative disclosure was provided in the notes to these consolidated financial statements.

PEMEX does not disclose amounts accrued for each individual claim because such disclosure could adversely affect PEMEX’s legal strategy, as well as the outcome of the related litigation.

Pursuant to an ordinary session held by the Board of Directors on August 23, 2013, Petróleos Mexicanos established policies for the granting of mutual guarantees, loans or any type of credit in favor of the Subsidiary Entities and Subsidiary Companies; in accordance with these policies, the Corporate Finance Department issues an opinion with its risk analysis, financial valuation, budget sufficiency, accounting treatment and conclusions.

F-127

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Additionally, Pemex Logistics has granted the following corporate guarantees in connection with the exploration and extraction contracts entered into Pemex Exploration and Production, as required by the NHC:

• Exploration and extraction of hydrocarbons under the deep-water license modality, Trión field (Tender CNH-A1-TRION / 2016), of US $4,000,000.

• Exploration and extraction of the contract area 3 Cinturón plegado perdido (Tender CNHR01- L04 / 2015), of US $3,333,000.

• Extraction of hydrocarbons under shared production contract of the Ek-Balam fields, of U.S. $5,000,000.

• Extraction of hydrocarbons in contractual area Santuario and El Golpe 3 field, of U.S. $320,000.

• Exploration and extraction of hydrocarbons under shared production contract, contractual area 2 Tampico-Misantla, of U.S. $1,750,000.

• Exploration and extraction of hydrocarbons under shared production contract, contractual area 8 Cuencas del Sureste, of U.S. $1,250,000.

• Exploration and extraction of hydrocarbons shared production contract, assignment AE-0398-Mission of U.S. $255,000.

• Extraction of hydrocarbons under license agreement, Ogarrio field of U.S. $250,000.

• Extraction of hydrocarbons under license agreement, Cárdenas and Mora fields, of U.S. $250,000.

Certain other Subsidiary Entities have also granted guarantees and other contingencies.

PEMEX considers the probability it needs to make a disbursement of cash, for the guarantees granted and in effect as of December 31, 2017 remote.

NOTE 26. BUSINESS COMBINATION

On January 28, 2016, PMX Fertilizantes Pacífico, S.A. de C.V., a PEMEX subsidiary company, acquired 99.99% of the outstanding shares of Fertinal, for a total purchase price of Ps. 4,322,826. This amount was paid through credit lines under a simple credit agreement. Additionally, within the same credit line, PMX Fertilizantes obtained U.S. $425,800 for the liquidation of Fertinal’s debt. These loans will mature in 16 years.

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The net fair value of Fertinal’s assets and liabilities as of the date of acquisition is:

	Fair value
Cash and cash equivalents	Ps.	(6,943	)
Accounts receivable		102,121
Inventories		762,254
Properties, plant and equipment		9,811,928
Other assets		1,671,718
Total assets		12,341,078
Accounts payable	Ps.	2,331,540
Debt		9,365,152
Deferred taxes		328,578
Total liabilities		12,025,270
Total assets, net	Ps.	315,808
Transaction value	Ps.	4,322,826
Goodwill	Ps.	4,007,018

PMX FP carried out the purchase price allocation (PPA) of the Fertinal acquisition in accordance with International Financial Reporting Standard 3 “Business Combination”. It was determined that net assets acquired amounted to Ps. 315,808 and a goodwill of Ps. 4,007,018. As of December 31, 2016, a calculation of the impairment of goodwill resulted in the complete cancellation of that amount. The impairment of goodwill is recognized in the consolidated statement of comprehensive income in other income (expenses), net. See Note 22.

PEMEX intends to incorporate Fertinal into the gas-ammonia solid fertilizers value chain in order to strengthen its ability to offer a wide range of fertilizers and to cover approximately 50% of the domestic market, and is also assessing the possibility of selling the integrated business in the future.

NOTE 27. SUBSEQUENT EVENTS

During the period from January 1 to April 27, 2018, PEMEX participated in the following financing activities:

• On February, 12, 2018, Petróleos Mexicanos issued U.S. $4,000,000 of debt securities under its U.S. $92,000,000 Medium-Term Notes Program, Series C, in two tranches: (1) U.S. $2,500,000,000 5.35% Notes due 2028 and (2) U.S. $1,500,000,000 6.35% Bonds due 2048. All debt securities under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

• On February 12, 2018, Petróleos Mexicanos consummated an exchange offer pursuant to which it exchanged (1) U.S. $952,454, aggregate principal amount of its outstanding 5.500% Bonds due 2044 for U.S. $881,899, aggregate principal amount of its new 6.350% Bonds due 2048 and (2) U.S. $1,021,065, aggregate principal amount of its outstanding 5.6250% Bonds due 2046 for U.S. $946,764, aggregate principal amount of its 6.350% Bonds due 2048.

F-129

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

• On March 5, 2018, Petróleos Mexicanos consummated a tender offer pursuant to which it purchased U.S. $138,598, aggregate principal amount of its outstanding 3.125% Notes due 2019, U.S. $558,644 aggregate principal amount of its outstanding 5.500% Notes due 2019, U.S. $91,843 aggregate principal amount of its outstanding 8.000% Notes due 2019, U.S. $183,017 aggregate principal amount of its outstanding 6.000% Notes due 2020 and U.S. $817,303 aggregate principal amount of its outstanding 3.500% Notes due 2020.

Between January 1 to April 27, 2018, PMI HBV obtained U.S. $7,126,000 and repaid U.S. $6,126,000 in financing from its revolving credit lines. As of April 27, 2018, the outstanding amount under these revolving credit lines was U.S. $1,227,500.

As of April 27, 2018, the Mexican peso-U.S. dollar exchange rate was Ps. 19.0530 per U.S. dollar, which represents a 3.7% appreciation of the value of the peso in U.S. dollar terms as compared to the exchange rate as of December 31, 2017, which was Ps. 19.7867 per U.S. dollar.

As of April 27, 2018, the weighted average price of the crude oil exported by PEMEX was U.S. $60.89 per barrel. This represents a price increase of approximately 8.3% as compared to the average price as of December 31, 2017, which was U.S. $56.19 per barrel.

In March 2018, Pemex Exploration and Production was summoned before the International Centre for Dispute Resolution of the American Arbitration Association in connection with an arbitration claim (No. 01-18-0001-1499) filed by Loadmaster Universal Rigs, Inc., Loadmaster Drilling Technologies, LLC, Ulterra Drilling Technologies Mexico, S.A. de C.V. and Kennedy Fabricating, LLC seeking U.S. $139,870 in connection with the construction and acquisition of modular drilling equipment. Pemex Exploration and Production is currently analyzing the legal actions available to it in response to this claim.

NOTE 28. SUBSIDIARY GUARANTOR INFORMATION

The following consolidating information presents: (i) condensed consolidated statements of financial position at December 31, 2017 and 2016 and condensed consolidated statements of comprehensive income and cash flows for the years ended December 31, 2017, 2016 and 2015 of Petróleos Mexicanos, the Subsidiary Guarantors and the Non-Guarantor Subsidiaries (as defined below).

These condensed consolidated statements were prepared in conformity with IFRS, with one exception: for the purposes of the presentation of the subsidiary guarantor information, the Subsidiary Entities and Subsidiary Companies have been accounted for as investments under the equity method by Petróleos Mexicanos. Earnings of subsidiaries are therefore reflected in Petróleos Mexicanos’ investment account and earnings. The principal elimination entries eliminate Petróleos Mexicanos’ investment in subsidiaries and inter-company balances and transactions. Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services (collectively, the “Subsidiary Guarantors”) and Pemex Ethylene and Pemex Fertilizers are 100%-owned subsidiaries of the Mexican Government. The guaranties by the Subsidiary Guarantors of Petróleos Mexicanos’ payment obligations under this indebtedness are full, unconditional, joint and several. Pemex Ethylene, Pemex Fertilizers, Pemex Finance, Ltd. and the Subsidiary Companies collectively comprise the non-guarantor subsidiaries (the “Non-Guarantor Subsidiaries”).

The Pemex Project Funding Master Trust (the “Master Trust”), which was a trust formed for the purpose of financing PEMEX’s projects, was dissolved effective December 20, 2011 and is no longer consolidated in the financial statements of PEMEX as of December 31, 2011 and thereafter.

F-130

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The following table sets forth, as of December 31, 2017, the principal amount outstanding of the registered debt securities originally issued by the Master Trust. As noted above, Petróleos Mexicanos has assumed, as primary obligor, all of the obligations of the Master Trust under these debt securities. The obligations of Petróleos Mexicanos are guaranteed by the Subsidiary Guarantors:

Table 1: Registered Debt Securities originally issued by the Master Trust and Assumed by Petróleos Mexicanos

Security	Primary obligor	Guarantors	Principal amount outstanding (U.S. $)
5.75% Guaranteed Notes due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		834,688
6.625% Guaranteed Bonds due 2035	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,750,000
6.625% Guaranteed Bonds due 2038	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		491,175
8.625% Bonds due 2022	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		160,245
8.625% Guaranteed Bonds due 2023	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		106,507
9 1⁄4% Guaranteed Bonds due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		107,109
9.50% Guaranteed Bonds due 2027	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		219,217

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PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

The following table sets forth, as of December 31, 2017, the principal amount outstanding of the registered debt securities issued by Petróleos Mexicanos, and guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

Table 2: Registered Debt Securities originally issued by Petróleos Mexicanos

Security	Issuer	Guarantors	Principal amount outstanding (U.S. $)
8.00% Notes due 2019	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,312,015
9 1⁄4% Global Guaranteed Bonds due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		9,296
9.50% Global Guaranteed Bonds due 2027	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		102,149
3.500% Notes due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		355,356
Floating Rate Notes due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		498,570
6.000% Notes due 2020	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		995,364
5.50% Notes due 2021	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,962,047

F-132

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Security	Issuer	Guarantors	Principal amount outstanding (U.S. $)
3.500% Notes due 2023	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,099,730
4.875% Notes due 2024	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,499,136
6.625% Notes due 2035	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		999,000
6.500% Bonds due 2041	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		3,000,000
4.875% Bonds 2022	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,097,055
3.125% Notes due 2019	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		325,778
3.500% Notes due 2020	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,465,367
5.50% Bonds due 2044	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,657,962

F-133

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Security	Issuer	Guarantors	Principal amount outstanding (U.S. $)
6.375% Bonds due en 2045	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,999,980
5.625% Bonds due 2046	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,996,226
4.500% Notes due 2026	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,489,718
4.250% Notes due 2025	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		998,435
5.500% Notes due 2019	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		740,851
6.375% Notes due 2021	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,247,668
6.875% Notes due 2026	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,970,334
4.625% Notes due 2023	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,055,498

F-134

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Security	Issuer	Guarantors	Principal amount outstanding (U.S. $)
6.750% Notes due 2047	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		3,671,628

Petróleos Mexicanos is the only PEMEX entity that had debt securities registered with the SEC outstanding as of December 31, 2017 and as of the date of these consolidated financial statements, and all guaranteed debt is issued by Petróleos Mexicanos. The guaranties of the Subsidiary Guarantors are full and unconditional and joint and several. PEMEX’s management has not presented separate financial statements for the Subsidiary Guarantors, because it has determined that such information is not material to investors.

F-135

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF FINANCIAL POSITION

As of December 31, 2017

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries		Eliminations			PEMEX consolidated
Assets
Current assets
Cash and cash equivalents	Ps.	46,959,103		Ps.	18,815,345		Ps.	32,077,306	Ps.	—		Ps.	97,851,754
Accounts receivable and other, net, and derivative financial instruments		83,119,394			38,105,354			79,533,940		—			200,758,688
Accounts receivable—inter-company		311,148,593			1,380,100,592			86,354,837		(1,777,604,022	)		—
Inventories		509,375			32,357,125			30,992,430		—			63,858,930
Available-for-sale financial assets		—			—			1,056,918		—			1,056,918
Total current assets		441,736,465			1,469,378,416			230,015,431		(1,777,604,022	)		363,526,290
Long-term receivables—intercompany		1,823,276,758			285			3,597,880		(1,826,874,923	)		—
Investments in joint ventures and associates		(465,832,399	)		82,668			16,611,681		465,845,414			16,707,364
Wells, pipelines, properties, plant and equipment-net		12,444,376			1,370,974,060			53,090,890		—			1,436,509,326
Long-term notes receivables		147,286,367			1,206,542			—		—			148,492,909
Deferred taxes		59,691,528			84,443,897			2,057,060		—			146,192,485
Intangible assets		—			9,088,563			—		—			9,088,563
Other assets		2,209,579			4,846,078			4,429,520		—			11,485,177
Total assets	Ps.	2,020,812,674		Ps.	2,940,020,509		Ps.	309,802,462	Ps.	(3,138,633,531	)	Ps.	2,132,002,114
Liabilities
Current liabilities
Current portion of long-term debt	Ps.	137,947,110		Ps.	5,386,564		Ps.	13,875,793	Ps.	—		Ps.	157,209,467
Accounts payable—inter-company		1,240,490,891			434,556,688			93,140,905		(1,768,188,484	)		—
Other current liabilities		23,435,614			157,589,107			50,892,997		—			231,917,718
Total current liabilities		1,401,873,615			597,532,359			157,909,695		(1,768,188,484	)		389,127,185
Long-term debt		1,824,829,579			40,262,391			15,573,634		—			1,880,665,604
Long-term payables—inter-company		—			1,830,150,615			6,139,845		(1,836,290,460	)		—
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		297,028,436			1,057,191,286			10,341,988		—			1,364,561,710
Total liabilities		3,523,731,630			3,525,136,651			189,965,162		(3,604,478,944	)		3,634,354,499
Equity (deficit), net		(1,502,918,956	)		(585,116,142	)		119,837,300		465,845,413			(1,502,352,385	)
Total liabilities and equity	Ps.	2,020,812,674		Ps.	2,940,020,509		Ps.	309,802,462	Ps.	(3,138,633,531	)	Ps.	2,132,002,114

F-136

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF FINANCIAL POSITION

As of December 31, 2016

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries		Eliminations			PEMEX consolidated
Assets
Current assets
Cash and cash equivalents	Ps.	92,503,607		Ps.	9,732,503		Ps.	61,296,403	Ps.	—		Ps.	163,532,513
Accounts receivable and other, net, and derivative financial instruments		6,604,595			75,760,079			55,713,323		—			138,077,997
Accounts receivable—inter-company		440,645,367			1,684,782,235			70,268,246		(2,195,695,848	)		—
Inventories		446,954			29,270,943			16,174,163		—			45,892,060
Available-for-sale financial assets		—			—			2,852,679		—			2,852,679
Held-for-sale non-financial assets		—			7,460,674			—		—			7,460,674
Total current assets		540,200,523			1,807,006,434			206,304,814		(2,195,695,848	)		357,815,923
Available-for-sale financial assets		—			—			6,027,540		—			6,027,540
Long-term receivables—intercompany		1,740,519,399			289			6,384,944		(1,746,904,632	)		—
Investments in joint ventures and associates		(250,108,630	)		396,681			20,327,813		250,121,645			20,737,509
Wells, pipelines, properties, plant and equipment-net		12,596,722			1,595,655,580			59,489,946		—			1,667,742,248
Long-term notes receivables		140,579,974			8,027,628			—		—			148,607,602
Deferred taxes		59,162,878			40,341,615			820,196		—			100,324,689
Restricted cash		—			9,624,804			853,822		—			10,478,626
Intangible assets		—			8,639,242			—		—			8,639,242
Other assets		1,824,104			2,707,788			4,980,753		—			9,512,645
Total assets	Ps.	2,244,774,970		Ps.	3,472,400,061		Ps.	305,189,828	Ps.	(3,692,478,835	)	Ps.	2,329,886,024
Liabilities
Current liabilities
Current portion of long-term debt		157,937,631			7,381,095			10,847,462		—			176,166,188
Accounts payable—inter-company		1,265,244,986			854,106,939			68,510,835		(2,187,862,760	)		—
Other current liabilities		34,913,773			169,182,239			45,927,686		—			250,023,698
Total current liabilities		1,458,096,390			1,030,670,273			125,285,983		(2,187,862,760	)		426,189,886
Long-term debt		1,737,332,174			46,090,919			23,581,449		—			1,807,004,542
Long-term payables—inter-company		—			1,746,433,870			8,303,850		(1,754,737,720	)		—
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		282,902,667			1,035,019,339			11,777,737		—			1,329,699,743
Total liabilities		3,478,331,231			3,858,214,401			168,949,019		(3,942,600,480	)		3,562,894,171
Equity (deficit), net		(1,233,556,261	)		(385,814,340	)		136,240,809		250,121,645			(1,233,008,147	)
Total liabilities and equity	Ps.	2,244,774,970		Ps.	3,472,400,061		Ps.	305,189,828	Ps.	(3,692,478,835	)	Ps.	2,329,886,024

F-137

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF COMPREHENSIVE INCOME

For the year ended December 31, 2017

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Net sales	Ps.	—		Ps.	1,713,914,703		Ps.	1,096,752,930		Ps.	(1,424,768,483	)	Ps.	1,385,899,150
Services income		50,399,983			140,934,022			2,646,144			(182,849,580	)		11,130,569
Total sales revenues		50,399,983			1,854,848,725			1,099,399,074			(1,607,618,063	)		1,397,029,719
Impairment of wells, pipelines, properties, plant and equipment		—			145,302,407			6,142,153			—			151,444,560
Cost of sales		2,007,814			1,447,640,131			1,083,297,610			(1,528,740,675	)		1,004,204,880
Gross income		48,392,169			261,906,187			9,959,311			(78,877,388	)		241,380,279
Other revenues (expenses), net		(341,521	)		(12,443,660	)		(4,664,096	)		22,623,353			5,174,076
General expenses:
Transportation, distribution and sale expenses		—			26,136,674			1,297,558			(5,544,562	)		21,889,670
Administrative expenses		59,141,391			105,920,390			5,883,200			(51,005,527	)		119,939,454
Total general expenses		59,141,391			132,057,064			7,180,758			(56,550,089	)		141,829,124
Operating income		(11,090,743	)		117,405,463			(1,885,543	)		296,054			104,725,231
Financing income		143,676,367			134,401,598			3,185,195			(265,097,307	)		16,165,853
Financing cost		(236,929,035	)		(141,900,236	)		(3,616,530	)		264,801,253			(117,644,548	)
Derivative financial instruments income (cost), net		27,670,991			(1,608,039	)		(724,628	)		—			25,338,324
Foreign exchange income , net		6,837,171			15,807,988			538,963			—			23,184,122
Profit (loss) sharing in joint ventures and associates		(211,567,169	)		409,955			(49,515	)		211,567,169			360,440
Income (loss) before taxes, duties and other		(281,402,418	)		124,516,729			(2,552,058	)		211,567,169			52,129,422
Total taxes, duties and other		(557,520	)		331,001,261			2,536,300			—			332,980,041
Net (loss) income for the year		(280,844,898	)		(206,484,532	)		(5,088,358	)		211,567,169			(280,850,619	)
Total other comprehensive result		4,728,640			6,841,586			(63,845	)		—			11,506,381
Total comprehensive result for the year	Ps.	(276,116,258	)	Ps.	(199,642,946	)	Ps.	(5,152,203	)	Ps.	211,567,169		Ps.	(269,344,238	)

F-138

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF COMPREHENSIVE INCOME

For the year ended December 31, 2016

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Net sales	Ps.	—		Ps.	1,361,538,624		Ps.	828,143,332		Ps.	(1,124,563,366	)	Ps.	1,065,118,590
Services income		46,330,245			98,959,131			1,970,055			(138,284,789	)		8,974,642
Total sales revenues		46,330,245			1,460,497,755			830,113,387			(1,262,848,155	)		1,074,093,232
(Reversal) impairment of wells, pipelines, properties, plant and equipment		—			(330,037,834	)		(1,276,509	)		—			(331,314,343	)
Cost of sales		1,236,921			1,244,388,072			809,156,778			(1,188,959,550	)		865,822,221
Gross income		45,093,324			546,147,517			22,233,118			(73,888,605	)		539,585,354
Other revenues (expenses), net		(312,611	)		20,713,184			2,915,837			(666,804	)		22,649,606
General expenses:
Transportation, distribution and sale expenses		—			50,948,771			945,489			(26,663,020	)		25,231,240
Administrative expenses		57,437,455			96,884,031			7,050,271			(48,718,224	)		112,653,533
Total general expenses		57,437,455			147,832,802			7,995,760			(75,381,244	)		137,884,773
Operating income		(12,656,742	)		419,027,899			17,153,195			825,835			424,350,187
Financing income		123,266,281			67,542,768			3,526,378			(180,586,172	)		13,749,255
Financing cost		(160,824,632	)		(114,271,762	)		(3,602,868	)		179,854,798			(98,844,464	)
Derivative financial instruments (cost) income, net		(12,052,200	)		3,172			(1,951,959	)		—			(14,000,987	)
Foreign exchange loss, net		(20,531,005	)		(232,714,446	)		(767,292	)		—			(254,012,743	)
Profit (loss) sharing in joint ventures and associates		(117,347,803	)		628,357			1,507,488			117,347,803			2,135,845
Income (loss) before taxes, duties and other		(200,146,101	)		140,215,988			15,864,942			117,442,264			73,377,093
Total taxes, duties and other		(8,834,626	)		266,155,181			7,200,880			—			264,521,435
Net (loss) income for the year		(191,311,475	)		(125,939,193	)		8,664,062			117,442,264			(191,144,342	)
Total other comprehensive result		10,126,560			96,032,433			21,713,488			—			127,872,481
Total comprehensive result for the year	Ps.	(181,184,915	)	Ps.	(29,906,760	)	Ps.	30,377,550		Ps.	117,442,264		Ps.	(63,271,861	)

F-139

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF COMPREHENSIVE INCOME

For the year ended December 31, 2015

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Net sales	Ps.	15,556		Ps.	1,523,767,800		Ps.	803,623,324		Ps.	(1,173,956,323	)	Ps.	1,153,450,357
Services income		16,897,139			16,815,589			2,585,617			(27,988,310	)		8,310,035
Total sales revenues		16,912,695			1,540,583,389			806,208,941			(1,201,944,633	)		1,161,760,392
Impairment of wells, pipelines, properties, plant and equipment		—			476,276,159			1,668,531			—			477,944,690
Benefit from change in pension plan					(83,657,496	)		(8,519,593	)		—			(92,177,089	)
Cost of sales		2,695,423			1,280,404,059			791,147,745			(1,182,282,621	)		891,964,606
Gross income		14,217,272			(132,439,333	)		21,912,258			(19,662,012	)		(115,971,815	)
Other (expenses) revenues, net		(19,805	)		(6,073,003	)		3,326,421			1,890,900			(875,487	)
General expenses:
Transportation, distribution and sale expenses		—			32,870,908			2,921,430			(6,863,699	)		28,928,639
Administrative expenses		59,923,878			52,832,029			10,638,127			(10,921,939	)		112,472,095
Benefit from change in pension plan		(46,031,780	)		(50,394,477	)		(7,434,698	)		—			(103,860,955	)
Total general expenses		13,892,098			35,308,460			6,124,859			(17,785,638	)		37,539,779
Operating income		305,369			(173,820,796	)		19,113,820			14,526			(154,387,081	)
Financing income		108,543,665			28,639,034			3,478,434			(125,670,274	)		14,990,859
Financing cost		(85,544,060	)		(104,453,148	)		(3,306,776	)		125,530,391			(67,773,593	)
Derivative financial instruments (cost) income, net		(22,803,663	)		6,463			1,347,323			—			(21,449,877	)
Foreign exchange loss, net		(14,829,436	)		(139,623,910	)		(312,228	)		—			(154,765,574	)
(Loss) profit sharing in joint ventures and associates		(749,963,960	)		198,786			2,119,329			749,963,960			2,318,115
(Loss) income before taxes, duties and other		(764,292,085	)		(389,053,571	)		22,439,902			749,838,603			(381,067,151	)
Total taxes, duties and other		(51,982,560	)		376,649,369			6,833,438			—			331,500,247
Net (loss) income for the year		(712,309,525	)		(765,702,940	)		15,606,464			749,838,603			(712,567,398	)
Total other comprehensive result		10,980,787			56,585,790			21,045,777			—			88,612,354
Total comprehensive result for the year	Ps.	(701,328,738	)	Ps.	(709,117,150	)	Ps.	36,652,241		Ps.	749,838,603		Ps.	(623,955,044)

F-140

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF CASH FLOWS

For the year ended December 31, 2017

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Operating activities:
Net (loss) income for the year	Ps.	(280,844,898	)	Ps.	(206,484,532	)	Ps.	(5,082,639	)	Ps.	211,561,450		Ps.	(280,850,619	)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization		1,155,881			152,607,943			2,940,689			—			156,704,513
Impairment of wells, pipelines, properties, plant and equipment		—			145,302,407			6,142,153			—			151,444,560
Unsuccessful wells		—			6,164,624			—			—			6,164,624
Exploration costs		—			(1,447,761	)		—			—			(1,447,761	)
Disposal of wells, pipelines, properties, plant and equipment		433,391			14,687,229			1,943,051			—			17,063,671
Gain on sale of share in joint ventures and associates		—			(3,139,103	)		—			—			(3,139,103	)
Disposal of held—for—sale current non—financial assets		—			2,808,360			—			—			2,808,360
Dividends		—			—			(180,675	)		—			(180,675	)
Effects of net present value of reserve for well abandonment		—			7,774,000			—			—			7,774,000
Profit (loss) sharing in investments		211,567,169			(409,955	)		49,515			(211,567,169	)		(360,440	)
Decrease on available—for-sale financial assets		—			—			1,360,205			—			1,360,205
Net loss on available-for-sale financial assets		—			—			3,523,748			—			3,523,748
Unrealized foreign exchange loss (gain)		(13,526,153	)		(1,585,910	)		(1,573,376	)		—			(16,685,439	)
Interest expense		100,545,114			15,736,420			1,363,014			—			117,644,548
Funds (used in) from operating activities:
Accounts receivable, accounts payable and derivative financial instruments		(88,496,967	)		(14,214,566	)		(20,789,692	)		—			(123,501,225	)
Inventories		(62,421	)		(3,086,181	)		(14,818,268	)		—			(17,966,870	)
Other assets		(7,091,867	)		(483,389	)		551,233			—			(7,024,023	)
Employee benefits		18,829,768			31,489,785			(254,157	)		—			50,065,396
Inter-company charges and deductions		7,284,124			(114,968,213	)		514,270			107,169,819			—
Cash flows (used in) from operating activities		(50,206,859	)		30,751,158			(24,310,929	)		107,164,100			63,397,470
Investing activities:
Acquisition of wells, pipelines, properties, plant and equipment		(1,436,926	)		(87,274,561	)		(3,147,978	)		—			(91,859,465	)
Resources from sale available-for-sale financial assets		—			—			8,026,836			—			8,026,836
Resources from sale of shares in associates		—			3,863,072			(721,362	)		—			3,141,710
(Increase) decrease due to Inter-company investing		25,611,359			—			—			(25,611,359	)		—
Cash flows used in investing activities		24,174,433			(83,411,489	)		4,157,496			(25,611,359	)		(80,690,919	)
Financing activities:
Loans obtained from financial institutions		401,947,349			—			302,768,119			—			704,715,468
Debt payments, principal only		(327,703,729	)		(7,981,937	)		(306,374,153	)		—			(642,059,819	)
Interest paid		(93,755,698	)		(13,991,633	)		(1,163,086	)		—			(108,910,417	)
Inter-company increase (decrease) financing		—			83,716,743			(2,164,002	)		(81,552,741	)		—
Cash flows provided by financing activities:		(19,512,078	)		61,743,173			(6,933,122	)		(81,552,741	)		(46,254,768	)
Net (decrease) increase in cash and cash equivalents		(45,544,504	)		9,082,842			(27,086,555	)		—			(63,548,217	)
Effects of change in cash value		—			—			(2,132,542	)		—			(2,132,542	)
Cash and cash equivalents at the beginning of the year		92,503,607			9,732,503			61,296,403			—			163,532,513
Cash and cash equivalents at the end of the year	Ps.	46,959,103		Ps.	18,815,345		Ps.	32,077,306		Ps.	—		Ps.	97,851,754

F-141

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF CASH FLOWS

For the year ended December 31, 2016

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Operating activities:
Net (loss) income for the year	Ps.	(191,311,476	)	Ps.	(139,410,398	)	Ps.	22,160,755		Ps.	117,416,777		Ps.	(191,144,342	)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization		1,066,033			146,545,307			2,828,151			—			150,439,491
(Reversal) impairment of wells, pipelines, properties, plant and equipment		—			(330,037,834	)		(1,276,509	)		—			(331,314,343	)
Unsuccessful wells		—			29,106,084			—			—			29,106,084
Exploration costs		—			(2,022,826	)		—			—			(2,022,826	)
Disposal of wells, pipelines, properties, plant and equipment		320,599			2,658,625			792,063			—			3,771,287
Loss in sale of fixed assets		—			27,882,480			—			—			27,882,480
Gain on sale of share in joint ventures and associates		—			(15,211,039	)		—			—			(15,211,039	)
Profit (loss) sharing in joint ventures and associates		117,249,643			(628,356	)		(1,507,489	)		(117,249,643	)		(2,135,845	)
Impairment of goodwill		—			—			4,007,018			—			4,007,018
Dividends		—			—			(293,397	)		—			(293,397	)
Effects of net present value of reserve for well abandonment		—			11,968,966			—			—			11,968,966
Unrealized foreign exchange loss (gain)		231,191,646			6,754,046			5,237,072			—			243,182,764
Interest expense		91,044,541			5,687,502			2,112,421			—			98,844,464
Funds (used in) from operating activities:
Accounts receivable, accounts payable and derivative financial instruments		23,636,331			(158,449,370	)		45,028,534			—			(89,784,505	)
Inventories		83,317			3,508,494			(4,950,690	)		—			(1,358,879	)
Other assets		(2,405,412	)		(22,600,504	)		(122,614	)		—			(25,128,530	)
Employee benefits		2,591,000			136,354,337			(91,652,268	)		—			47,293,069
Inter-company charges and deductions		(393,835,932	)		(83,049,125	)		48,435,633			428,449,424			—
Cash flows (used in) from operating activities		(120,369,710	)		(380,943,611	)		30,798,680			428,616,558			(41,898,083	)
Investing activities:
Acquisition of wells, pipelines, properties, plant and equipment		(2,172,586	)		(147,786,686	)		(1,449,208	)		—			(151,408,480	)
Resources from sale on share in associates		—			23,050,344			(365,608	)		—			22,684,736
Proceeds from the sale of fixed assets		—			560,665			—			—			560,665
Business acquisition		—			—			(4,329,769	)		—			(4,329,769	)
(Increase) decrease due to Inter-company investing		(39,612,699	)		—			—			39,612,699			—
Cash flows used in investing activities		(41,785,285	)		(124,175,677	)		(6,144,585	)		39,612,699			(132,492,848	)
Financing activities:
Increase in equity due to Certificates of Contributions “A”		73,500,000			—			—			—			73,500,000
Loans obtained from financial institutions		571,944,209			34,483,348			235,564,210			—			841,991,767
Debt payments, principal only		(372,809,166	)		(6,414,441	)		(235,763,722	)		—			(614,987,329	)
Interest paid		(82,008,347	)		(4,706,946	)		(2,038,848	)		—			(88,754,141	)
Inter-company increase (decrease) financing		—			464,488,030			3,741227			(468,229,257	)		—
Cash flows provided by financing activities:		190,626,696			487,849,991			1,502,867			(468,229,257	)		211,750,297
Net (decrease) increase in cash and cash equivalents		28,471,701			(17,269,297	)		26,156,962			—			37,359,366
Effects of change in cash value		5,570,892			20,371,126			(9,137,751	)		—			16,804,267
Cash and cash equivalents at the beginning of the year		58,461,014			6,630,674			44,277,192			—			109,368,880
Cash and cash equivalents at the end of the year	Ps.	92,503,607		Ps.	9,732,503		Ps.	61,296,403		Ps.	—		Ps.	163,532,513

F-142

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF CASH FLOWS

For the year ended December 31, 2015

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Operating activities:
Net (loss) income for the year	Ps.	(712,177,124	)	Ps.	(765,702,826	)	Ps.	15,738,868		Ps.	749,573,684		Ps.	(712,567,398	)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization		789,657			164,221,429			2,940,164			—			167,951,250
Impairment of wells, pipelines, properties, plant and equipment		—			476,276,159			1,668,531			—			477,944,690
Unsuccessful wells		—			23,213,519			—			—			23,213,519
Exploration costs		—			(5,698,511	)		—			—			(5,698,511	)
Disposal of wells, pipelines, properties, plant and equipment		180,992			21,945,266			2,512,279			—			24,638,537
Profit (loss) sharing in joint ventures and associates		749,963,958			(198,786	)		(2,119,329	)		(749,963,958	)		(2,318,115	)
Gain on sale of share in joint ventures and associates		—			(337,675	)		(342,955	)		—			(680,630	)
Dividends		—			—			(359,941	)		—			(359,941	)
Effects of net present value of reserve for well abandonment		—			(608,160	)		—			—			(608,160	)
Unrealized foreign exchange loss (gain)		145,971,158			2,996,219			3,708,879			—			152,676,256
Interest expense		63,460,443			3,414,430			898,720			—			67,773,593
Funds provided by (used in) operating activities:
Accounts receivable, accounts payable and derivative financial instruments		(58,554,144	)		119,761,648			(27,777,939	)		—			33,429,565
Inventories		108,568			4,547,843			1,511,317			—			6,167,728
Other assets		(149,819	)		(16,578,827	)		126,281			—			(16,602,365	)
Employee benefits		(10,037,444	)		(94,183,192	)		(11,801,596	)		—			(116,022,232	)
Inter-company charges and deductions		(310,384,820	)		30,044,041			31,975,215			248,365,564			—
Cash flows provided by operating activities		(130,828,575	)		(36,887,423	)		18,678,494			247,975,290			98,937,786
Investing activities:
Acquisition of wells, pipelines, properties, plant and equipment		(1,496,277	)		(239,315,507	)		(12,702,217	)		—			(253,514,001	)
Investments in associates		—			—			(36,214	)		—			(36,214	)
Resources from the sales on share in associates		—			(130,323	)		4,547,461			—			4,417,138
(Increase) decrease due to Inter-company investing		(39,108,879	)		—			—			39,108,879			—
Cash flows used in investing activities		(40,605,156	)		(239,445,830	)		(8,190,970	)		39,108,879			(249,133,077	)
Financing activities:
Increase in equity due to Certificates of Contributions “A”		10,000,000			(1,915,922	)		1,844,394			71,528			10,000,000
Loans obtained from financial institutions		345,383,990			—			33,587,088			—			378,971,078
Debt payments, principal only		(147,927,857	)		(8,081,177	)		(37,609,464	)		—			(193,618,498	)
Interest paid		(58,123,368	)		(3,443,923	)		(1,169,859	)		—			(62,737,150	)
Inter-company increase (decrease) financing		(3,626,448	)		289,859,173			922,972			(287,155,697	)		—
Cash flows provided by financing activities:		145,706,317			276,418,151			(2,424,869	)		(287,084,169	)		132,615,430
Net (decrease) increase in cash and cash equivalents		(25,727,414	)		84,898			8,062,655			—			(17,579,861	)
Effects of change in cash value		11,185,788			1,138,356			(3,363,931	)		—			8,960,213
Cash and cash equivalents at the beginning of the year		73,002,640			5,407,420			39,578,468			—			117,988,528
Cash and cash equivalents at the end of the year	Ps.	58,461,014		Ps.	6,630,674		Ps.	44,277,192		Ps.	—		Ps.	109,368,880

F-143

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

NOTE 29. SUPPLEMENTARY INFORMATION ON OIL AND GAS EXPLORATION AND PRODUCTION ACTIVITIES (UNAUDITED)

Under the Mexican Constitution, all crude oil and other hydrocarbon reserves located in the subsoil of Mexico are owned by the Mexican nation and not by PEMEX. In August 2014, through the Round Zero process, the Mexican Government granted PEMEX the right to extract, but not own, certain petroleum and other hydrocarbon reserves in Mexico through assignment deeds.

This note provides supplementary information on the oil and gas exploration, development and production activities of Pemex Exploration and Production in compliance with the U.S. Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 932 10-5 “Extractive Activities—Oil and Gas” (“ASC Topic 932”) and Accounting Standards Update 2010-03 (see Note 3(i)).

As of the date of these consolidated financial statements, all exploration and production activities of Pemex Exploration and Production are conducted in Mexico. The supplemental data presented herein reflect information for all of Pemex Exploration and Production’s oil and gas producing activities.

a. Capitalized costs for oil and gas producing activities (unaudited):

	As of December 31,
	2017			2016			2015
Proved reserves	Ps.	2,363,336,481		Ps.	2,476,535,503		Ps.	2,102,971,025
Construction in progress		35,381,089			60,720,261			88,706,330
Accumulated depreciation and amortization		(1,444,962,317	)		(1,355,402,150	)		(1,224,690,867	)
Net capitalized costs	Ps.	953,755,253		Ps.	1,181,853,614		Ps.	966,986,487

b. Costs incurred for oil and gas property exploration and development activities (unaudited):

	As of December 31,
	2017		2016
Exploration	Ps.	32,480,801	Ps.	41,661,666
Development		53,460,364		113,895,246
Total costs incurred	Ps.	85,941,165	Ps.	155,556,912

There are no property acquisition costs because PEMEX exploits oil reserves owned by the Mexican nation.

Exploration costs include costs for geological and geophysical studies of fields amounting to Ps. 8,828,809 and Ps. 6,804,341, for 2017 and 2016, respectively, that, in accordance with the successful efforts method of accounting, are accounted for as geological and geophysical exploration expenses.

Development costs include costs incurred in obtaining access to proved reserves and providing facilities for extracting, treating, gathering and storing oil and gas.

F-144

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

c. Results of operations for oil and gas producing activities (unaudited):

	2017			2016			2015
Revenues from sale of oil and gas	Ps.	762,637,362		Ps.	616,380,608		Ps.	690,591,455
Hydrocarbon duties		375,156,405			304,299,019			376,682,705
Production costs (excluding taxes)		248,957,950			171,194,337			177,774,082
Other costs and expenses		(3,954,222	)		61,359,271			20,360,540
Exploration expenses		14,993,433			39,693,273			31,244,564
Depreciation, depletion, amortization and accretion		240,672,906			(150,891,739	)		527,014,056
		875,826,472			425,654,161			1,133,075,947
Results of operations for oil and gas producing activities	Ps.	(113,189,111	)	Ps.	190,726,447		Ps.	(442,484,491	)

Note: Numbers may not total due to rounding.

d. Sales prices (unaudited)

The following table summarizes average sales prices in U.S. dollars for each of the years ended December 31 (excluding production taxes):

	2017		2016		2015
Weighted average sales price per barrel of oil equivalent (boe)(1)	US$	38.63	US$	29.18	US$	37.17
Crude oil, per barrel		48.71		36.55		48.22
Natural gas, per thousand cubic feet		4.32		3.01		3.78

(1) To convert dry gas to barrels of oil equivalent, a factor of 5.201 thousand cubic feet of dry gas per barrel of oil equivalent is used.

e. Crude oil and natural gas reserves (unaudited)

Under the Mexican Constitution, all oil and other hydrocarbon reserves located in the subsoil of Mexico are owned by the Mexican nation and not by PEMEX. Under the Petróleos Mexicanos Law, Pemex Exploration and Production has the right to extract, but not own, these reserves, and to sell the resulting production. The exploration and development activities of Petróleos Mexicanos and the Subsidiary Entities are limited to reserves located in Mexico.

Proved oil and natural gas reserves are those estimated quantities of crude oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be economically producible from a given date forward, from known reservoirs and under existing economic conditions, operating methods and government regulations.

Proved reserves estimates as of December 31, 2017 were prepared by the exploration and production segment and were reviewed by the Independent Engineering Firms (as defined below), which audit its estimates of its hydrocarbon reserves. In addition, pursuant to the Reglamento de la Ley de Hidrocarburos (Regulations to the Hydrocarbons Law), on March 23, 2018 the NHC reviewed and approved the proved reserves estimates as of December 31, 2017.

F-145

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Pemex Exploration and Production estimates reserves based on generally accepted petroleum engineering and evaluation methods and procedures, which are based primarily on applicable SEC regulations and, as necessary, the SPE’s publication entitled Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information, dated February 19, 2007 and other SPE publications, including the SPE’s publication entitled Petroleum Resources Management System, as well as other technical sources, including Estimation and Classification of Reserves of Crude Oil, Natural Gas, and Condensate, by Chapman Cronquist, and Determination of Oil and Gas Reserves, Petroleum Society Monograph Number 1, published by the Canadian Institute of Mining and Metallurgy & Petroleum. The choice of method or combination of methods employed in the analysis of each reservoir is determined by:

• Experience in the area

• Stage of development

• Quality and completeness of basic data

• Production and pressure histories

Reserves data set forth herein represents only estimates. Reserves valuation is a subjective process of estimating underground accumulations of crude oil and natural gas that cannot be measured in an exact manner. The accuracy of any reserves estimate depends on the quality of available data, engineering and geological interpretation and professional judgment. As a result, estimates of different engineers may vary. In addition, the results of drilling, testing and producing subsequent to the date of an estimate may lead to the revision of an estimate.

During 2017, PEMEX did not record any material increase in PEMEX’s hydrocarbons reserves as a result of the use of new technologies.

In order to ensure the reliability of PEMEX’s reserves estimation efforts, it has undertaken the internal certification of its estimates of reserves since 1996. PEMEX has established certain internal controls in connection with the preparation of its proved reserves estimates. Initially, teams of geoscientists from Pemex Exploration and Production’s exploration and exploitation business units (with each of these units covering several projects) prepare the reserves estimates, using distinct estimation processes for valuations relating to new discoveries and developed fields, respectively. Subsequently, the regional reserves offices collect these reserves estimates from the units and request that the Gerencia de Recursos y Certificación de Reservas (Office of Resources and Reserves Certification), the central hydrocarbon reserves management body of Pemex Exploration and Production, review and certify such valuations and the booking of the related reserves. This internal certification process is undertaken in accordance with internal guidelines for estimating and classifying hydrocarbon reserves, which are based on the SEC’s rules and definitions. The Office of Resources and Reserves Certification, which additionally oversees and conducts an internal audit of the above process, consists entirely of professionals with geological, geophysical, petrophysical and reservoir engineering backgrounds. The engineers who participate in PEMEX’s reserves estimation process are experienced in: reservoir numerical simulation; well drilling and completion; pressure, volume and temperature (PVT) analysis; analytical tools used in forecasting the performance of the various elements comprising the production system; and design strategies in petroleum field development. Furthermore, all of PEMEX’s personnel have been certified by the Secretaría de Educación Pública (Ministry of Public Education), most have earned master’s degrees in areas of study such as petroleum engineering, geology and geophysical engineering and they possess an average of over fifteen years of professional experience.

F-146

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

In addition to this internal review process, Pemex Exploration and Production’s final reserves estimates are audited by independent engineering firms. Three independent engineering firms audited Pemex Exploration and Production’s estimates of proved reserves as of December 31, 2017: Netherland Sewell International, S. de R. L. de C. V. (“Netherland Sewell”); DeGolyer and MacNaughton (“DeGolyer”); and Ryder Scott Company, L.P. (“Ryder Scott,”) and, together with Netherland Sewell and DeGolyer and MacNaughton, the “Independent Engineering Firms”. The reserves estimates reviewed by the Independent Engineering Firms totaled 97.0% of PEMEX’s estimated proved reserves. The remaining 3.0% of PEMEX’s estimated proved reserves consisted of reserves located in certain areas in which third parties provide drilling services to Pemex Exploration and Production. Under such agreements, the corresponding third party is responsible of assessing the volume of reserves.

Netherland Sewell audited the reserves in the Poza Rica-Altamira, Aceite Terciario del Golfo and Litoral de Tabasco assets. DeGolyer in Burgos and Veracruz Assets and Ryder Scott audited the reserves in the Bellota-Jujo, Cinco Presidentes, Macuspana-Muspac, Samaria-Luna, Abkatún-Pol-Chuc, Cantarell and Ku-Maloob-Zaap Assets. The audits conducted by the Independent Engineering Firms consisted primarily of: (1) analysis of historical static and dynamic reservoir data provided by Pemex-Exploration and Production; (2) construction or updating of the Independent Engineering Firms’ own static and dynamic reservoir characterization models of some of the fields; (3) economic analysis of the fields; and (4) review of Pemex Exploration and Production’s production forecasts and reserves estimates.

Since reserves estimates are, by definition, only estimates, they cannot be reviewed for the purpose of verifying exactness. Instead, the Independent Engineering Firms conducted a detailed review of Pemex Exploration and Production’s reserves estimates so that they could express an opinion as to whether, in the aggregate, the reserves estimates that Pemex Exploration and Production furnished were reasonable and had been estimated and presented in conformity with generally accepted petroleum engineering and evaluation methods and procedures.

All questions, including any suggested modifications to proved reserves estimates, that arose during the Independent Engineering Firms’ review process were resolved by Pemex Exploration and Production to the satisfaction of the Independent Engineering Firms. The Independent Engineering Firms have concluded that PEMEX’s estimated total proved oil and natural gas reserve volumes set forth in this report are, in the aggregate, reasonable and have been prepared in accordance with Rule 4-10(a) are consistent with international reserves reporting practice and are in accordance with the revised oil and gas reserves disclosure provisions of ASC Topic 932.

PEMEX’s total proved developed and undeveloped reserves of crude oil, condensates and liquefiable hydrocarbons recoverable from field processing plants decreased by 11.0% in 2017, from 7,219 million barrels at December 31, 2016 to 6,427 million barrels at December 31, 2017. PEMEX’s proved developed reserves of crude oil, condensates and liquefiable hydrocarbons recoverable from processing plants decreased by 14.7% in 2017, from 4,866 million barrels at December 31, 2016 to 4,166 million barrels at December 31, 2017. These decreases were principally due to oil production in 2017, a decrease in field development activities and field behavior and the transfer to third parties, who were awarded with contracts in the bidding rounds, of certain

F-147

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

fields that had been temporarily assigned to PEMEX and associations and alliances such as Santuario and El Golpe fields, of which PEMEX is assigned a 64% of their proved reserves . The amount of crude oil, condensate and liquefiable hydrocarbon reserves added in 2017 was insufficient to offset the level of production in 2017, which amounted to 805.5 million barrels of crude oil, condensates and liquefiable hydrocarbons.

PEMEX’s proved developed and undeveloped dry gas reserves decreased by 5.6% in 2017, from 6,984 billion cubic feet at December 31, 2016 to 6,593 billion cubic feet at December 31, 2017. PEMEX’s proved developed dry gas reserves decreased by 10.8% in 2017, from 4,513 billion cubic feet at December 31, 2016 to 4,026 billion cubic feet at December 31, 2017. These decreases were principally due to oil production in 2017, a decrease in field development activities and field behavior and the transfer to third parties, who were awarded with contracts in the bidding rounds, of certain fields that had been temporarily assigned to PEMEX and associations and alliances such as Santuario and El Golpe fields, of which PEMEX is assigned a 64% of their proved reserves. The amount of dry gas reserves added in 2017 was insufficient to offset the level of production in 2017, which amounted to 999 billion cubic feet of dry gas. PEMEX’s proved undeveloped dry gas reserves increased by 3.9% in 2017, from 2,471 billion cubic feet at December 31, 2016 to 2,567 billion cubic feet at December 31, 2017.

During 2017, our exploratory activity in the shallow waters of the Gulf of Mexico and onshore regions resulted in new discoveries of light crude oil in the offshore Suuk field in June 2017 and gas and condensate discoveries in the onshore Valeriana and lxachi fields in August and November of 2017, respectively. These discoveries led to the incorporation of approximately 246 million barrels of oil equivalent in three fields.

The following three tables of crude oil and dry gas reserves set forth PEMEX’s estimates of its proved reserves determined in accordance with Rule 4-10(a).

Summary of oil and gas⁽¹⁾ proved reserves as of December 31, 2017

based on average fiscal year prices

	Crude oil and Condensates(2)		Dry Gas(3)
	(in millions of barrels)		(in billions of cubic feet)
Proved developed and un-developed reserves:
Proved developed reserves		4,166		4,026
Proved undeveloped reserves		2,261		2,567
Total proved reserves		6,427		6,593

Note: Numbers may not total due to rounding.

(1) PEMEX does not currently produce synthetic oil or synthetic gas, or other natural resources from which synthetic oil or synthetic gas can be produced.

(2) Crude oil and condensate reserves include the fraction of liquefiable hydrocarbons recoverable in natural gas processing plants located at fields.

(3) Reserve volumes reported in this table are volumes of dry gas, although natural gas production reported in other tables refers to sour wet gas. There is a shrinkage in volume when natural gas liquids and impurities are extracted to obtain dry gas. Therefore, reported natural gas volumes are greater than dry gas volumes.

Source: Pemex Exploration and Production.

F-148

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Crude oil and condensate reserves

(including natural gas liquids)⁽¹⁾

	2017			2016			2015
	(in millions of barrels)
Proved developed and undeveloped reserves:
At December 31		7,219			7,977			10,292
Revisions(2)		(95	)		189			(1,491	)
Extensions and discoveries		147			(55	)		111
Production		(805	)		(891	)		(935	)
Farm outs & transfer of fields due to NHC bidding process		(38	)		—			—
At December 31		6,427			7,219			7,977
Proved developed reserves at December 31		4,166			4,886			5,725
Proved undeveloped reserves at December 31		2,261			2,333			2,252

Note: Numbers may not total due to rounding.

(1) Crude oil and condensate reserves include the fraction of liquefiable hydrocarbons recoverable in natural gas processing plants located at fields.

(2) Revisions include positive and negative changes due to new data from well drilling, revisions made when actual reservoir performance differs from expected performance and changes in hydrocarbon prices.

Source: Pemex Exploration and Production.

Dry gas reserves

	2017			2016			2015
	(in billions of cubic feet)
Proved developed and undeveloped reserves:
At December 31		6,984			8,610			10,859
Revisions(1)		169			(183	)		(955	)
Extensions and discoveries		468			(308	)		47
Production(2)		(999	)		(1,134	)		(1,341	)
Farm outs & transfer of fields due to NHC bidding process		(29	)		—			—
At December 31		6,593			6,984			8,610
Proved developed reserves at December 31		4,026			4,513			6,012
Proved undeveloped reserves at December 31		2,567			2,471			2,598

Note: Numbers may not total due to rounding.

(1) Revisions include positive and negative changes due to new data from well drilling, revisions made when actual reservoir performance differs from expected performance and changes in hydrocarbon prices.

(2) Production refers here to dry gas, although natural gas production reported in other tables refers to sour wet gas. There is a shrinkage in volume when natural gas liquids and impurities are extracted to obtain dry gas. Therefore, reported natural gas volumes are greater than dry gas volumes.

Source: Pemex Exploration and Production.

Pemex Exploration and Production’s reserve-replacement ratio, or RRR, for a given period is calculated by dividing the sum of proved reserves additions due to discoveries, developments, delineations and revisions by that period’s total production. During 2017, we obtained an increase of 174.2 million barrels of oil equivalent of

F-149

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

proved reserves as aggregated from discoveries, revisions, delimitations and development and production, which represents a RRR of 17.5 %. PEMEX’s 2017 RRR is an improvement as compared to 2016, when the RRR was 4.0%. PEMEX expects continued improvements in its RRR in subsequent years.

PEMEX’s reserves production ratio, which is presented in terms of years, is calculated by dividing the estimated remaining reserves at the end of the relevant year by the total production of hydrocarbons for that year. As of December 31, 2017, this ratio stayed constant with 2016 levels and was equal to 7.7 years for proved reserves.

f. Standardized measure of discounted future net cash flows related to proved oil and gas reserves (unaudited)

The standardized measure tables presented below relate to proved oil and gas reserves excluding proved reserves scheduled to be produced after the year 2042. This measure is presented in accordance with ASC Topic 932.

Estimated future cash inflows from production are computed by applying average prices of oil and gas on the first day of each month of 2017. Future development and production costs are those estimated future expenditures needed to develop and produce the year-end estimated proved reserves after a net cash flows discount factor of 10%, assuming constant year-end economic conditions.

Future tax expenses are computed by applying the appropriate year-end statutory tax rates with consideration of the tax rates of the new fiscal regime for Pemex Exploration and Production already legislated for 2017 to the future pre-tax net cash flows related to PEMEX’s proved oil and gas reserves.

The estimated future payment of taxes was calculated based on fiscal regime applicable by decree to Pemex-Exploration and Production effective January 1, 2015 and by the tax benefits published in the Official Gazette of the Federation on April 18, 2016.

The standardized measure provided below represents a comparative benchmark value rather than an estimate of expected future cash flows or fair market value of PEMEX’s production rights. There are numerous uncertainties inherent in estimating quantities of proved reserves and in projecting future rates of production and timing of development expenditures, including many factors beyond the control of the producer. Accordingly, reserve estimates may be materially different from the quantities of crude oil and natural gas that are ultimately recovered.

F-150

PETRÓLEOS MEXICANOS, PRODUCTIVE STATE-OWNED SUBSIDIARIES

AND SUBSIDIARY COMPANIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2017, 2016 AND 2015

(FIGURES STATED IN THOUSANDS, EXCEPT AS NOTED)

Standardized measure of discounted future net cash flows as of December 31

	2017			2016			2015
	(in millions of U.S. dollars)
Future cash inflows	US$	269,489		US$	228,196		US$	325,052
Future production costs (excluding profit taxes)		(114,369	)		(87,942	)		(99,948	)
Future development costs		(26,229	)		(25,515	)		(32,560	)
Future cash flows before tax		128,891			114,738			192,544
Future production and excess gains taxes		(129,377	)		(108,960	)		(167,056	)
Future net cash flows		(487	)		5,779			25,488
Effect of discounting net cash flows by 10%		(4,600	)		(937	)		(9,946	)
Standardized measure of discounted future net cash flows	US$	4,113		US$	4,841		US$	15,541

Note: Table amounts may not total due to rounding.

To comply with ASC Topic 932, the following table presents the aggregate standardized measure changes for each of the last three years and significant sources of variance:

Changes in standardized measure of discounted future net cash flows

	2017			2016			2015
	(in millions of U.S. dollars)
Sales of oil and gas produced, net of production costs	US$	(25,076	)	US$	(19,411	)	US$	(28,371	)
Net changes in prices and production costs		26,355			(53,278	)		(327,865	)
Extensions and discoveries		3,639			1,105			3,086
Development cost incurred during the year		2,699			4,124			10,172
Changes in estimated development costs		2,744			1,763			(2,171	)
Reserves revisions and timing changes		(1,353	)		6,366			(22,801	)
Accretion of discount of pre-tax net cash flows		5,891			11,094			43,394
Net changes in production and excess gains taxes		(15,628	)		37,537			295,437
Aggregate change in standardized measure of discounted future net cash flows	US$	(728	)	US$	(10,700	)	US$	(29,119	)
Standardized measure:
As of January 1	US$	4,841		US$	15,541		US$	44,661
As of December 31		4,113			4,841			15,541
Change	US$	(728	)	US$	(10,700	)	US$	(29,119	)

Note: Table amounts may not total due to rounding.

In computing the amounts under each factor of change, the effects of variances in prices and costs are computed before the effects of changes in quantities. Consequently, changes in reserves are calculated at December 31 prices and costs.

The change in computed taxes includes taxes effectively incurred during the year and the change in future tax expense.

F-151

EX-2.26

Exhibit 2.26

EIGHTH SUPPLEMENTAL INDENTURE

EIGHTH SUPPLEMENTAL INDENTURE (the “Eighth Supplemental Indenture”), dated as of February 16, 2018, between Petróleos Mexicanos (the “Issuer”), having its principal office at Avenida Marina Nacional No. 329, Colonia Petróleos Mexicanos, Mexico City, 11300, Mexico, and Deutsche Bank Trust Company Americas, as trustee (the “Trustee”).

W I T N E S S E T H:

WHEREAS, the Issuer and the Trustee previously have entered into an Indenture, dated as of January 27, 2009 (the “Original Indenture” and, as supplemented by the first supplemental indenture (the “First Supplemental Indenture”), dated as of June 2, 2009, among the Issuer, the Trustee and Deutsche Bank AG, London Branch, by the second supplemental indenture (the “Second Supplemental Indenture”), dated as of October 13, 2009, among the Issuer, Credit Suisse AG and BNP Paribas (Suisse) S.A., by the third supplemental indenture (the “Third Supplemental Indenture”), dated as of April 10, 2012, among the Issuer, the Trustee and Credit Suisse AG, by the fourth supplemental indenture (the “Fourth Supplemental Indenture”), dated as of June 24, 2014, between the Issuer and the Trustee, by the fifth supplemental indenture (the “Fifth Supplemental Indenture”), dated as of October 15, 2014, between the Issuer and the Trustee, by the sixth supplemental indenture (the “Sixth Supplemental Indenture”), dated as of December 8, 2015, among the Issuer, the Trustee, BNP Paribas (Suisse) SA, as principal Swiss paying and authenticating agent, and Credit Suisse AG, as an additional Swiss paying agent, by the seventh supplemental indenture (the “Seventh Supplemental Indenture”), dated as of June 14, 2016 among the Issuer, the Trustee, Credit Suisse AG, as principal Swiss paying and authenticating agent, and UBS AG, as an additional Swiss paying agent, and by this Eighth Supplemental Indenture and by any further supplements thereto, the “Indenture”), providing for the issuance from time to time of unsecured bonds, debentures, notes and other evidences of indebtedness (the “Securities”) of the Issuer to be issued in one or more series as provided in the Indenture;

WHEREAS, pursuant to Section 9.02 of the Original Indenture, the Issuer and the Trustee may amend or supplement certain provisions of the Indenture and the Securities with the consent of Holders of not less than a majority in aggregate principal amount of the then Outstanding Securities;

WHEREAS, the Issuer desires to amend a certain provision of the Indenture;

WHEREAS, pursuant to an Offer to Purchase and Consent Solicitation Statement dated February 1, 2018 (as amended and supplement from time to time, the “Statement”), and a related Consent and Letter of Transmittal dated February 1, 2018 (the “Consent and Letter of Transmittal”) the Issuer solicited the consents of the Holders of the 5.500% Notes due 2019 (the “Solicited Series”) to a proposed amendment to the Indenture as it relates to the Solicited Series (the “Amendment”) and the Holders of at least a majority in aggregate principal amount of the Solicited Series (with respect to any Solicited Series, the “Required Consents”) duly consented to the Amendment pursuant to Section 9.02 of the Original Indenture at or prior to 5:00 p.m. (New York City time) on February 14, 2018 (the “Early Tender Date”);

WHEREAS, the Issuer has heretofore delivered, or is delivering contemporaneously herewith, to the Trustee (i) a Board Resolution authorizing the execution of this Eighth Supplemental Indenture, (ii) evidence of the written consent of the Holders of not less than a majority in aggregate principal amount Outstanding of the Solicited Series and (iii) the Opinion of Counsel described in Section 9.03 of the Original Indenture;

WHEREAS, the Issuer has duly authorized the execution and delivery of this Eighth Supplemental Indenture for the foregoing purposes;

WHEREAS, all conditions necessary to authorize the execution and delivery of this Eighth Supplemental Indenture and to make this Eighth Supplemental Indenture valid and binding have been complied with or have been done or performed; and

WHEREAS, the Issuer has requested that the Trustee execute and deliver this Eighth Supplemental Indenture.

NOW, THEREFORE, for and in consideration of the premises and the mutual covenants contained herein and in the Indenture and for other good and valuable consideration, the receipt and sufficiency of which are herein acknowledged, the Issuer and the Trustee hereby agree, for the equal and ratable benefit of all Holders, as follows:

ARTICLE ONE

DEFINITIONS

Section 1.01. Defined Terms. All capitalized terms used but not defined herein shall have the meanings ascribed to such terms in the Indenture, as supplemented and amended hereby. As used in this Eighth Supplemental Indenture, “Consent Solicitation Completion Date” shall mean such time as each of the following events shall have occurred with respect to the Solicited Series in accordance with the terms and conditions of the Statement and the Consent and Letter of Transmittal: (i) the Issuer shall have completed (and not terminated) the offers to purchase the Solicited Series; and (ii) the Issuer shall have purchased all validly tendered and accepted notes of the Solicited Series. All definitions in the Original Indenture shall be read in a manner consistent with the terms of this Eighth Supplemental Indenture.

ARTICLE TWO

AMENDMENT TO INDENTURE

Section 2.01. With respect to the Solicited Series, upon the occurrence of a Consent Solicitation Completion Date, the first paragraph of Section 11.05 of the Indenture solely as it relates and applies to the Solicited Series shall be amended and restated in its entirety as follows:

“Notice of redemption shall be given not less than three (3) Business Days nor more than ten (10) days prior to the Redemption Date to each Holder of the Securities of any series to be redeemed in accordance with Section 1.06.”

Section 2.02. With respect to the Solicited Series, upon the occurrence of a Consent Solicitation Completion Date and without any further action by any party hereto, any provision contained in each Global Security representing the notes of the Solicited Series that relates to the section in the Indenture that is amended pursuant to Section 2.01 hereof shall likewise be amended so that any such provision contained in such Global Security will conform to and be consistent with the Indenture, as amended by this Eighth Supplemental Indenture.

ARTICLE THREE

MISCELLANEOUS

Section 3.01. Effect of Supplemental Indenture. This Eighth Supplemental Indenture supplements the Original Indenture, as supplemented by the First Supplemental Indenture, the Second Supplemental Indenture, the Third Supplemental Indenture, the Fourth Supplemental Indenture, the Fifth Supplemental Indenture, the Sixth Supplemental Indenture and the Seventh Supplemental Indenture, and shall be a part, and subject to all the terms, thereof solely with respect to the Solicited Series. The Original Indenture, as supplemented and amended by the First Supplemental Indenture, the Second Supplemental Indenture, the Third Supplemental Indenture, the Fourth Supplemental Indenture, the Fifth Supplemental Indenture, the Sixth Supplemental Indenture, the Seventh Supplemental Indenture and this Eighth Supplemental Indenture, is in all respects ratified and confirmed, and the Original Indenture, as supplemented by the First Supplemental Indenture, the Second Supplemental Indenture, the Third Supplemental Indenture, the Fourth Supplemental Indenture, the Fifth Supplemental Indenture, the Sixth Supplemental Indenture, the Seventh Supplemental Indenture and this Eighth Supplemental Indenture, solely as it relates and applies to the Solicited Series shall be read, taken and construed as one and the same instrument. All provisions included in this Eighth Supplemental Indenture supersede any conflicting provisions

included in the Original Indenture solely as it relates and applies to the Solicited Series, unless not permitted by law. The Trustee accepts the trusts created by the Original Indenture, as supplemented by this Eighth Supplemental Indenture, and agrees to perform the same upon the terms and conditions of the Original Indenture, as supplemented by this Eighth Supplemental Indenture.

Section 3.02. Governing Law. This Eighth Supplemental Indenture shall be governed by and construed in accordance with the laws of the State of New York, except that all matters relating to the authorization and execution of this Eighth Supplemental Indenture and the Securities by the Issuer will be governed by the laws of Mexico.

Section 3.03. Notices. All notices and communications hereunder shall be given in the manner set forth in Section 1.05 of the Indenture.

Section 3.04. Effect of Headings. The section headings herein are for convenience only and shall not affect the construction of this Eighth Supplemental Indenture.

Section 3.05. Counterparts. The parties may sign any number of copies of this Eighth Supplemental Indenture. Each signed copy shall be an original, but all of them shall represent the same agreement.

Section 3.06. Liability of Trustee. The Trustee shall not be responsible in any manner whatsoever for or in respect of the validity or sufficiency of this Eighth Supplemental Indenture or for or in respect of the recitals contained herein, all of which recitals are made solely by the Issuer.

[SIGNATURE PAGE TO FOLLOW IMMEDIATELY]

IN WITNESS WHEREOF, the parties have caused this Eighth Supplemental Indenture to be duly executed by their respective officers thereunto duly authorized as of the day and year first above written.

PETRÓLEOS MEXICANOS
By:	/s/ CARLOS CARAVEO SÁNCHEZ
Name:	Carlos Caraveo Sánchez
Title:	Associate Managing Director of Finance
	of Petróleoes Mexicanos

DEUTSCHE BANK TRUST COMPANY AMERICAS, as Trustee
By:	Deutsche Bank National Trust Company
By:	/s/ IRINA GOLOVASHCHUK
Name:	Irina Golovashchuk
Title:	Vice President
By:	/s/ JEFFREY SCHOENFELD
Name:	Jeffrey Schoenfeld
Title:	Vice President

EX-7.1

Exhibit 7.1

PETRÓLEOS MEXICANOS, SUBSIDIARY ENTITIES AND SUBSIDIARY COMPANIES

Computation of ratio of earnings to fixed charges

(In thousands of Mexican pesos)

	2017			2016			2015			2014			2013
IFRS
Fixed Charges:
Interest capitalized in fixed assets		3,060,963			3,667,752			5,258,854			3,997,121			2,943,597
Interest expense		140,350,860			132,681,656			99,271,197			73,657,618			54,067,022
Amortization premiums related to indebtedness		(2,109,778	)		(1,610,183	)		(2,229,657	)		312,296			(1,890,710	)
Estimate of the interest within rental expense		418,883			500,654			450,760			242,436			159,380
Total Fixed Charges		141,720,928			135,239,879			102,681,154			78,209,471			55,279,289
Net income (loss)		(280,850,619	)		(191,144,342	)		(712,567,398	)		(265,542,989	)		(170,058,427	)
Hydrocarbon Income Tax (IRP)		—			—			—			(18,735,301	)		3,787,543
Income Tax and Others		(5,064,168	)		(12,640,369	)		(45,587,267	)		3,773,966			3,672,466
Cumulative effect of adoption of new accounting standards		—			—			—			—			—
Profit sharing in subsidiaries and affiliates (income from equity investees)		(360,440	)		(2,135,845	)		(2,318,115	)		(34,368	)		(706,710	)
Pretax income from continuing operations before income from equity investees		(286,275,227	)		(205,920,556	)		(760,472,780	)		(280,538,692	)		(163,305,128	)
Fixed Charges:		141,720,928			135,239,879			102,681,154			78,209,471			55,279,289
Amortization of interest capitalized		122,439			146,710			210,354			159,885			117,744
Distributed income of investments shares		180,675			293,397			359,941			736,302			914,116
Interest capitalized in fixed assets		(3,060,963	)		(3,667,752	)		(5,258,854	)		(3,997,121	)		(2,943,597	)
Earnings		(147,312,148	)		(73,908,322	)		(662,480,185	)		(205,430,155	)		(109,937,576	)
Amount by which fixed charges exceed earnings		289,033,076			209,148,201			765,161,339			283,639,626			165,216,865
Ratio of earnings to fixed charges		—			—			—			—			—

EX-10.1

		EXHIBIT 10.1 (Part 1 of 2)
TBPE REGISTERED ENGINEERING FIRM F-1580		FAX (713) 651-0849
1100 LOUISIANA SUITE 4600	HOUSTON, TEXAS 77002-5294	TELEPHONE (713) 651-9191
	April 26, 2018

Ing. Carlos Alberto Treviño Medina

Petróleos Mexicanos

Avenida Marina Nacional 329

Torre Ejecutiva, Piso 44

Colonia Verónica Anzures

11300 Ciudad de México, México

Ing. Treviño Medina:

We hereby consent to the references to Ryder Scott Company, L.P. as set forth under the heading “Exploration and Production (Reserves)” in the annual report on Form 20-F of Petróleos Mexicanos (“Pemex”) for the year ended December 31, 2017 (the “Form 20-F”) and to the filing as an exhibit to the Form 20-F our report, dated April 20, 2018, describing our review of the estimates of Pemex’s proved oil condensate, natural gas and oil equivalent reserves as of December 31, 2017, for 36 fields located offshore from Mexico in the Northeastern Marine Region and Southwestern Marine Region. These estimates were prepared in accordance with the applicable reserves definitions of Rule 4-10(a) of Regulation S-X of the United States Securities and Exchange Commission

RYDER SCOTT COMPANY, L.P.

TBPE Registration No. F-1580

SUITE 800, 350 7TH AVENUE, S.W.	CALGARY, ALBERTA T2P 3N9	TEL (403) 262-2799	FAX (403) 262-2790
621 17TH STREET, SUITE 1550	DENVER, COLORADO 80293-1501	TEL (303) 623-9147	FAX (303) 623-4258

		EXHIBIT 10.1 (Part 2 of 2)
TBPE REGISTERED ENGINEERING FIRM F-1580		FAX (713) 651-0849
1100 LOUISIANA SUITE 4600	HOUSTON, TEXAS 77002-5294	TELEPHONE (713) 651-9191
	April 26, 2018

Ing. Carlos Alberto Treviño Medina

Petróleos Mexicanos

Avenida Marina Nacional 329

Torre Ejecutiva, Piso 44

Colonia Verónica Anzures

11300 Ciudad de México, México

Dear Ing. Treviño Medina:

We hereby consent to the references to Ryder Scott Company, L.P. as set forth under the heading “Exploration and Production (Reserves)” in the annual report on Form 20-F of Petróleos Mexicanos (“Pemex”) for the year ended December 31, 2017 (the “Form 20-F”) and to the filing as an exhibit to the Form 20-F our report, dated April 20, 2018, describing our review of the estimates of Pemex’s proved oil condensate, natural gas and oil equivalent reserves as of December 31, 2017, for 88 fields located onshore in Mexico in the Southern Region. These estimates were prepared in accordance with the applicable reserves definitions of Rule 4-10(a) of Regulation S-X of the United States Securities and Exchange Commission

RYDER SCOTT COMPANY, L.P.

TBPE Registration No. F-1580

SUITE 800, 350 7TH AVENUE, S.W.	CALGARY, ALBERTA T2P 3N9	TEL (403) 262-2799	FAX (403) 262-2790
621 17TH STREET, SUITE 1550	DENVER, COLORADO 80293-1501	TEL (303) 623-9147	FAX (303) 623-4258

EX-10.2

Exhibit 10.2

(Part 1 of 2)

Pemex Exploración y Producción

Estimated

Future Reserves

Attributable to Certain Offshore

Oil and Gas Properties in Mexico

Activo Abkatun-Pol-Chuc

Activo Cantarell

Activo Ku-Maloob-Zaap

SEC Parameters

As of

December 31, 2017

Guale Ramirez, P.E.

TBPE License No.48318

Executive Vice President

RYDER SCOTT COMPANY, L.P.

TBPE Firm Registration No. F-1580

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

TBPE REGISTERED ENGINEERING  FIRM F-1580		FAX (713) 651-0849
1100 LOUISIANA SUITE 4600	HOUSTON, TEXAS 77002-5294	TELEPHONE (713) 651-9191

April 20, 2018

Ing. J. Javier Hinojosa Puebla

Director General de Pemex Exploración y Producción

Avenida Marina Nacional 329

Torre Ejecutiva, Piso 41

Col. Verónica Anzúres, C.P. 11300

Del. Miguel Hidalgo, Ciudad de México

Dear Ing. Hinojosa Puebla,

At the request of Pemex Exploración y Producción (PEP), a wholly owned subsidiary of Petróleos Mexicanos (Pemex), Ryder Scott Company, L.P. (Ryder Scott) has conducted a reserves audit of the estimates of the proved reserves owned by the United Mexican States as of December 31, 2017. The properties reviewed by us are operated by Pemex. The estimates we audited were prepared by PEP’s engineering and geological staff based on the definitions and disclosure guidelines of the United States Securities and Exchange Commission contained in Title 17, Code of Federal Regulations, Modernization of Oil and Gas Reporting, Final Rule released January 14, 2009, in the Federal Register (SEC regulations). Our third party reserves audit, completed on February 28, 2018, and presented herein, was prepared for public disclosure by Pemex in filings made with the SEC in accordance with the disclosure requirements set forth in the SEC regulations. The properties reviewed by Ryder Scott in this report are comprised of those properties contractually awarded to PEP and located in three areas of operations known as Activos. The names of these Activos as well as their geographical locations are shown below:

Activo Abkatun-Pol-Chuc	Offshore Mexican territorial waters, Gulf of Mexico
Activo Cantarell	Offshore Mexican territorial waters, Gulf of Mexico
Activo Ku-Maloob-Zaap	Offshore Mexican territorial waters, Gulf of Mexico

The proved net reserves attributable to the properties that we reviewed account for 100 percent of the total proved net oil equivalent barrels (BOE) of PEP for the Activos listed above.

As prescribed by the Society of Petroleum Engineers in Paragraph 2.2(f) of the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information (SPE auditing standards), a reserves audit is defined as “the process of reviewing certain of the pertinent facts interpreted and assumptions made that have resulted in an estimate of reserves and/or Reserves Information prepared by others and the rendering of an opinion about (1) the appropriateness of the methodologies employed; (2) the adequacy and quality of the data relied upon; (3) the depth and thoroughness of the reserves estimation process; (4) the classification of reserves appropriate to the relevant definitions used; and (5) the reasonableness of the estimated reserve quantities and/or Reserves Information.” Reserves Information may consist of various estimates pertaining to the extent and value of petroleum properties.

Based on our review, including the data, technical processes and interpretations presented by PEP, it is our opinion that the overall procedures and methodologies utilized by PEP in preparing their estimates of the proved reserves as of December 31, 2017 comply with the current SEC regulations, and that the overall proved reserves for the reviewed properties as estimated by PEP are, in the aggregate, reasonable within the established audit tolerance guidelines of 10 percent set forth in the SPE auditing standards.

SUITE 800, 350 7TH AVENUE, S.W.	CALGARY, ALBERTA T2P 3N9	TEL (403) 262-2799	FAX (403) 262-2790
621 17TH STREET, SUITE 1550	DENVER, COLORADO 80293-1501	TEL (303) 623-9147	FAX (303) 623-4258

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The estimated reserves presented in this report are related to hydrocarbon prices. PEP has informed us that in the preparation of their reserve and income projections, as of December 31, 2017, they used average prices during the 12-month period prior to the “as of date” of this report, determined as the unweighted arithmetic averages of the prices in effect on the first-day-of-the-month for each month within such period, unless prices were defined by contractual arrangements, as required by the SEC regulations. Actual future prices may vary significantly from the prices required by SEC regulations; therefore, volumes of reserves actually recovered may differ significantly from the estimated quantities presented in this report. The net reserves as estimated by PEP attributable to the properties that we reviewed are summarized below:

SEC PARAMETERS

Estimated Net Reserves

Attributable to Certain Properties

Abkatun-Pol-Chuc, Cantarell, and Ku-Maloob-Zaap

As of December 31, 2017

	Proved
	Developed						Total
	Producing		Non-Producing		Undeveloped		Proved
Net Reserves of Properties
Audited by Ryder Scott
Oil/Condensate – MM Barrels		2,155.1		707.3		1,017.8		3,880.2
Plant Products(1) – MM Barrels		99.4		70.0		51.2		220.6
Dry Gas(2) – MM Barrels Equivalent		157.1		110.7		80.9		348.7
BOE(3) – MM Barrels		2,411.6		888.0		1,149.9		4,449.5
Gross Gas(4) – MMMCF		1,317.0		976.7		669.0		2,962.7

(1) Includes liquids generated through the transportation process and at the petrochemical plants.

(2) Dry Gas reserves are the dry, sweetened gas available for sale by Pemex - Gas y Petroquímica Básica at the tailgate of the processing plants.

(3) Barrels of oil-equivalent are based on dry gas conversion factors provided by PEP.

(4) Gross Gas represents produced volumes of gas before any losses for fuel use, venting, transporting or plant shrinkage.

(5) May not match the sum of the reserves sub-classes exactly due to rounding.

Liquid hydrocarbons are expressed in standard 42 gallon barrels and are shown in millions of barrels (MM Barrels). All gas volumes are reported on an “as-sold” basis expressed in billions of cubic feet (MMMCF) at the official temperature and pressure bases of the areas in which the gas reserves are located. The net remaining reserves are also shown herein on an equivalent unit (BOE) basis wherein natural gas is converted to oil equivalent barrels using a specific factor for each field. MMBOE represents million barrels of oil equivalent.

Reserves Included in This Report

In our opinion, the proved reserves reviewed by us and presented in this report conform to the definition as set forth in the Securities and Exchange Commission’s Regulations Part 210.4-10(a). An abridged version of the SEC reserves definitions from 210.4-10(a) entitled “Petroleum Reserves Definitions” is included as an attachment to this report.

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The various proved reserve status categories are defined under the attachment entitled “Petroleum Reserves Status Definitions and Guidelines” in this report. The proved developed non-producing reserves included herein consist of the shut-in and behind pipe categories.

Reserves are “estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations.” All reserve estimates involve an assessment of the uncertainty relating the likelihood that the actual remaining quantities recovered will be greater or less than the estimated quantities determined as of the date the estimate is made. The uncertainty depends chiefly on the amount of reliable geologic and engineering data available at the time of the estimate and the interpretation of these data. The relative degree of uncertainty may be conveyed by placing reserves into one of two principal categories, either proved or unproved. Unproved reserves are less certain to be recovered than proved reserves and may be further sub-categorized as probable and possible reserves to denote progressively increasing uncertainty in their recoverability. At PEP’s request, this report addresses only the proved reserves attributable to the properties reviewed herein.

Proved oil and gas reserves are those quantities of oil and gas which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward.” The proved reserves included herein were estimated using deterministic methods. If deterministic methods are used, the SEC has defined reasonable certainty for proved reserves as a “high degree of confidence that the quantities will be recovered.”

Proved reserve estimates will generally be revised only as additional geologic or engineering data become available or as economic conditions change. For proved reserves, the SEC states that “as changes due to increased availability of geoscience (geological, geophysical, and geochemical), engineering, and economic data are made to the estimated ultimate recovery (EUR) with time, reasonably certain EUR is much more likely to increase or remain constant than to decrease.” Moreover, estimates of proved reserves may be revised as a result of future operations, effects of regulation by governmental agencies or geopolitical or economic risks. Therefore, the proved reserves included in this report are estimates only and should not be construed as being exact quantities, and if recovered, could be more or less than the estimated amounts.

Audit Data, Methodology, Procedure and Assumptions

The estimation of reserves involves two distinct determinations. The first determination results in the estimation of the quantities of recoverable oil and gas and the second determination results in the estimation of the uncertainty associated with those estimated quantities in accordance with the definitions set forth by the Securities and Exchange Commission’s Regulations Part 210.4-10(a). The process of estimating the quantities of recoverable oil and gas reserves relies on the use of certain generally accepted analytical procedures. These analytical procedures fall into three broad categories or methods: (1) performance-based methods; (2) volumetric-based methods; and (3) analogy. These methods may be used individually or in combination by the reserve evaluator in the process of estimating the quantities of reserves. Reserve evaluators must select the method or combination of methods that in their professional judgment is most appropriate given the nature and amount of reliable geoscience and engineering data available at the time of the estimate, the established or anticipated performance characteristics of the reservoir being evaluated and the stage of development or producing maturity of the property.

RYDER SCOTT COMPANY    PETROLEUM CONSULTANTS

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In many cases, the analysis of the available geoscience and engineering data and the subsequent interpretation of this data may indicate a range of possible outcomes in an estimate, irrespective of the method selected by the evaluator. When a range in the quantity of reserves is identified, the evaluator must determine the uncertainty associated with the incremental quantities of the reserves. If the reserve quantities are estimated using the deterministic incremental approach, the uncertainty for each discrete incremental quantity of the reserves is addressed by the reserve category assigned by the evaluator. Therefore, it is the categorization of reserve quantities as proved, probable and/or possible that addresses the inherent uncertainty in the estimated quantities reported. For proved reserves, uncertainty is defined by the SEC as reasonable certainty wherein the “quantities actually recovered are much more likely than not to be achieved.” The SEC states that “probable reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered.” The SEC states that “possible reserves are those additional reserves that are less certain to be recovered than probable reserves and the total quantities ultimately recovered from a project have a low probability of exceeding proved plus probable plus possible reserves.” All quantities of reserves within the same reserve category must meet the SEC definitions as noted above.

Estimates of reserves quantities and their associated reserve categories may be revised in the future as additional geoscience or engineering data become available. Furthermore, estimates of reserves quantities and their associated reserve categories may also be revised due to other factors such as changes in economic conditions, results of future operations, effects of regulation by governmental agencies or geopolitical or economic risks as previously noted herein.

The proved reserves prepared by PEP for the properties that we reviewed were estimated by performance methods, the volumetric method, analogy, or a combination of methods. Approximately 60 percent of the proved producing reserves attributable to producing wells and/or reservoirs that we reviewed were estimated by performance methods. These performance methods include, but may not be limited to, decline curve analysis, numerical simulation and material balance, which utilized extrapolations of historical production and pressure data available through December 2017, in those cases where such data were considered to be definitive. The data utilized in these analyses were furnished to Ryder Scott by PEP and were considered sufficient for the purpose thereof. The remaining 40 percent of the proved producing reserves that we reviewed were estimated by the volumetric method, analogy, or a combination of methods. These methods were used where there were inadequate historical performance data to establish a definitive trend and where the use of production performance data as a basis for the reserve estimates was considered to be inappropriate.

All of the proved developed non-producing and undeveloped reserves that we reviewed were estimated by the volumetric method, analogy, or a combination of methods. Volume versus depth analytical volumetric models that considered historical production volumes as well as movements of oil-water and gas-oil contacts with time were also utilized for certain major properties located offshore. The volumetric analysis utilized pertinent well and seismic data furnished to Ryder Scott by PEP for our review that were available through December 2017. The data utilized from the analogues in conjunction with well and seismic data incorporated into the volumetric analysis were considered sufficient for the purpose thereof.

To estimate economically recoverable proved oil and gas reserves many factors and assumptions are considered including, but not limited to, the use of reservoir parameters derived from geological, geophysical and engineering data which cannot be measured directly, economic criteria based on current costs and SEC pricing requirements, and forecasts of future production rates. Under the SEC regulations 210.4-10(a)(22)(v) and (26), proved reserves must be anticipated to be economically producible from a given date forward based on existing economic conditions including the

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

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prices and costs at which economic producibility from a reservoir is to be determined. While it may reasonably be anticipated that the future prices received for the sale of production and the operating costs and other costs relating to such production may increase or decrease from those under existing economic conditions, such changes were, in accordance with rules adopted by the SEC, omitted from consideration in conducting this review.

As stated previously, proved reserves must be anticipated to be economically producible from a given date forward based on existing economic conditions including the prices and costs at which economic producibility from a reservoir is to be determined. To confirm that the proved reserves reviewed by us meet the SEC requirements to be economically producible, we have reviewed certain primary economic data utilized by PEP relating to hydrocarbon prices and costs as noted herein.

The hydrocarbon prices furnished by PEP for the properties reviewed by us are based on SEC price parameters using the average prices during the 12-month period prior to the “as of date” of this report, determined as the unweighted arithmetic averages of the prices in effect on the first-day-of-the-month for each month within such period, unless prices were defined by contractual arrangements. For hydrocarbon products sold under contract, the contract prices, including fixed and determinable escalations exclusive of inflation adjustments, were used until expiration of the contract. Upon contract expiration, the prices were adjusted to the 12-month unweighted arithmetic average as previously described.

The initial SEC hydrocarbon prices in effect on December 31, 2017 for the properties reviewed by us were determined using the 12-month average first-day-of-the-month prices appropriate to the geographic areas where the hydrocarbons are sold. These prices are the actual prices received by PEP for the sale of hydrocarbon products to its affiliates such as Pemex - Refinación.

The table below summarizes PEP’s net volume weighted prices adjusted for differentials for the properties reviewed by us by geographic areas and referred to herein as PEP’s “average realized prices.” The average realized prices shown in the table below were determined from PEP’s estimate of the total future gross revenue before production taxes for the properties reviewed by us and PEP’s estimate of the total net reserves for the properties reviewed by us for each of the areas referred to as Activos as listed below. The data shown in the table below is presented in accordance with SEC disclosure requirements for each of the geographic areas shown and reviewed by us.

Geographic Area (Activo)	Product		Average Realized Prices
Abkatun-Pol-Chuc		Oil/Condensate	$	55.41/Bbl
		Gas	$	5.56/MCF
Cantarell		Oil/Condensate	$	46.81/Bbl
		Gas	$	4.45/MCF
Ku-Maloob-Zaap		Oil/Condensate	$	41.14/Bbl
		Gas	$	5.13/MCF

The effects of derivative instruments designated as price hedges of oil and gas quantities are not reflected in PEP’s individual property evaluations.

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Accumulated gas production imbalances, if any, were not taken into account in the proved gas reserve estimates reviewed. The proved gas volumes included herein do not attribute gas consumed in operations as reserves.

Operating costs furnished by PEP are based on the operating expense reports of PEP and include only those costs directly applicable to the fields or wells for the properties reviewed by us. The operating costs include a portion of general and administrative costs allocated directly to the fields and wells. The operating costs furnished by PEP were accepted as factual data and reviewed by us for their reasonableness; however, we have not conducted an independent verification of the data used by PEP. No deduction was made for loan repayments, interest expenses, or exploration and development prepayments that were not charged directly to the fields, wells or contract areas.

Development costs furnished by PEP are based on authorizations for expenditure for the proposed work or actual costs for similar projects. The development costs furnished by PEP were accepted as factual data and reviewed by us for their reasonableness; however, we have not conducted an independent verification of the data used by PEP. The estimated net cost of abandonment after salvage was included by Pemex for properties where abandonment costs net of salvage were significant. Pemex’s estimates of the net abandonment costs were accepted without independent verification.

The proved developed non-producing and undeveloped reserves for the properties reviewed by us have been incorporated herein in accordance with PEP’s plans to develop these reserves as of December 31, 2017. The implementation of these development plans as presented to us is subject to the approval process adopted by PEP’s management. As the result of our inquiries during the course of our review, PEP has informed us that the development activities for the properties reviewed by us have been subjected to and received the internal approvals required by PEP’s management at the appropriate local, regional and/or corporate level. Additionally, PEP has informed us that they are not aware of any legal, regulatory or political obstacles that would significantly alter their plans. While these plans could change from those under existing economic conditions as of December 31, 2017, such changes were, in accordance with rules adopted by the SEC, omitted from consideration in making this evaluation.

Current costs used by PEP were held constant throughout the life of the properties.

PEP’s forecasts of future production rates are based on historical performance from wells currently on production. If no production decline trend has been established, future production rates were held constant until a decline in ability to produce was anticipated. An estimated rate of decline was then applied to depletion of the reserves. If a decline trend has been established, this trend was used as the basis for estimating future production rates.

Test data and other related information were used by PEP to estimate the anticipated initial production rates for those wells or locations that are not currently producing. For reserves not yet on production, sales were estimated to commence at an anticipated date furnished by PEP. Wells or locations that are not currently producing may start producing earlier or later than anticipated in PEP’s estimates due to unforeseen factors causing a change in the timing to initiate production. Such factors may include delays due to weather, the availability of rigs, the sequence of drilling, completing and/or recompleting wells and/or constraints set by regulatory bodies.

The future production rates from wells currently on production or wells or locations that are not currently producing may be more or less than estimated because of changes including, but not limited to, reservoir performance, operating conditions related to surface facilities, compression and artificial lift, pipeline capacity and/or operating conditions, producing market demand and/or allowables or other constraints set by regulatory bodies.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

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Ryder Scott did not evaluate the country and geopolitical risks in the country of Mexico where all of the subject properties are located. PEP’s operations may be subject to various levels of governmental controls and regulations. These controls and regulations may include, but may not be limited to, matters relating to land tenure and use, drilling and production practices, environmental protection, marketing and pricing policies, various taxes and levies and are subject to change from time to time. Such changes in governmental regulations and policies may cause volumes of proved reserves actually recovered and amounts of proved income actually received to differ significantly from the estimated quantities.

The estimates of proved reserves presented herein were based upon a review of the subject properties; however, we have not made any field examination of the properties. No consideration was given in this report to potential environmental liabilities that may exist nor were any costs included by PEP for potential liabilities to restore and clean up damages, if any, caused by past operating practices.

Certain technical personnel of PEP are responsible for the preparation of reserve estimates on new properties and for the preparation of revised estimates, when necessary, on old properties. These personnel assembled the necessary data and maintained the data and workpapers in an orderly manner. We consulted with these technical personnel and had access to their workpapers and supporting data in the course of our audit.

PEP has informed us that they have furnished us all of the material accounts, records, geological and engineering data, and reports and other data required for this investigation. In performing our audit of PEP’s forecast of future proved production, we have relied upon data furnished by PEP with respect to property interests, production and well tests from examined wells, normal direct costs of operating the properties, other costs such as transportation and/or processing fees, recompletion and development costs, development plans, abandonment costs after salvage, product prices based on the SEC regulations, adjustments or differentials to product prices, geological structural and isochore maps, well logs, core analyses, and pressure measurements. Ryder Scott reviewed such factual data for its reasonableness; however, we have not conducted an independent verification of the data furnished by PEP. The data described herein were accepted as authentic and sufficient for determining the reserves unless, during the course of our examination, a matter of question came to our attention in which case the data were not accepted until all questions were satisfactorily resolved. We consider the factual data furnished to us by PEP to be appropriate and sufficient for the purpose of our review of PEP’s estimates of reserves. In summary, we consider the assumptions, data, methods and analytical procedures used by PEP and as reviewed by us appropriate for the purpose hereof, and we have used all such methods and procedures that we consider necessary and appropriate under the circumstances to render the conclusions set forth herein.

Audit Opinion

Based on our review, including the data, technical processes and interpretations presented by PEP, it is our opinion that the overall procedures and methodologies utilized by PEP in preparing their estimates of the proved reserves as of December 31, 2017 comply with the current SEC regulations and that the overall proved reserves in terms of barrels of oil equivalent (BOE) for the reviewed properties as estimated by PEP are, in the aggregate, reasonable within the established audit tolerance guidelines of 10 percent as set forth in the SPE auditing standards. Ryder Scott found the processes and controls used by PEP in their estimation of proved reserves to be effective and, in the aggregate, we found no bias in the utilization and analysis of data in estimates for these properties.

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We were in reasonable agreement with PEP’s estimates of proved reserves for the properties which we reviewed; however, in certain cases there was more than an acceptable variance between PEP’s estimates and our estimates due to a difference in interpretation of data or due to our having access to data which were not available to PEP when its reserve estimates were prepared. In these cases, PEP revised its estimates to better conform to our estimates. As a consequence, it is our opinion that on an aggregate basis the data presented herein for the properties that we reviewed fairly reflects the estimated net reserves for those properties owned by the United Mexican States.

Standards of Independence and Professional Qualification

Ryder Scott is an independent petroleum engineering consulting firm that has been providing petroleum consulting services throughout the world since 1937. Ryder Scott is employee-owned and maintains offices in Houston, Texas; Denver, Colorado; and Calgary, Alberta, Canada. We have over eighty engineers and geoscientists on our permanent staff. By virtue of the size of our firm and the large number of clients for which we provide services, no single client or job represents a material portion of our annual revenue. We do not serve as officers or directors of any privately-owned or publicly-traded oil and gas company and are separate and independent from the operating and investment decision-making process of our clients. This allows us to bring the highest level of independence and objectivity to each engagement for our services.

Ryder Scott actively participates in industry-related professional societies and organizes an annual public forum focused on the subject of reserves evaluations and SEC regulations. Many of our staff have authored or co-authored technical papers on the subject of reserves related topics. We encourage our staff to maintain and enhance their professional skills by actively participating in ongoing continuing education.

Prior to becoming an officer of the Company, Ryder Scott requires that staff engineers and geoscientists have received professional accreditation in the form of a registered or certified professional engineer’s license or a registered or certified professional geoscientist’s license, or the equivalent thereof, from an appropriate governmental authority or a recognized self-regulating professional organization.

We are independent petroleum engineers with respect to PEP. Neither we nor any of our employees have any financial interest in the subject properties, and neither the employment to do this work nor the compensation is contingent on our estimates of reserves for the properties which were reviewed.

The results of this audit, presented herein, are based on technical analysis conducted by teams of geoscientists and engineers from Ryder Scott. The professional qualifications of the undersigned, the technical person primarily responsible for the review of the reserves information discussed in this report, are included as an attachment to this letter.

Terms of Usage

The results of our third party audit, presented in report form herein, were prepared in accordance with the disclosure requirements set forth in the SEC regulations and intended for public disclosure as an exhibit in filings made with the SEC by Pemex.

Pemex makes periodic filings on Form 20-F with the SEC under the 1934 Exchange Act. Furthermore, Pemex files registration statements with the SEC under the 1933 Securities Act into which filings on Form 20-F are incorporated by reference. We have consented to the references to our name

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in and the filing of this report as an exhibit to the annual report on Form 20-F of Pemex for the year ended December 31, 2017. Our written consent for such use will be included as a separate exhibit to such Form 20-F. In the event the references to our name as well as references to our report are incorporated by reference into any registration statement on Form F-4, then our written consent for such use will be included as a separate exhibit to such registration statement.

We have provided PEP with a digital version of the original signed copy of this report letter. In the event there are any differences between the digital version included in filings made by Pemex and the original signed report letter, the original signed report letter shall control and supersede the digital version.

The data and workpapers used in the preparation of this report are available for examination by authorized parties in our offices. Please contact us if we can be of further service.

Very truly yours,

RYDER SCOTT COMPANY, L.P.

TBPE Firm Registration No. F-1580

Guale Ramirez, P.E.

TBPE License No. 48318

Executive Vice President

GR (DPR)/pl

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

Professional Qualifications of Primary Technical Person

The conclusions presented in this report are the result of technical analysis conducted by teams of geoscientists and engineers from Ryder Scott Company, L.P. Guadalupe Ramirez was the primary technical person responsible for overseeing the estimate of the reserves, future production and income.

Mr. Ramirez, an employee of Ryder Scott Company, L.P. (Ryder Scott) since 1981, is the Executive Vice President and also serves as a member of the Board of Directors. He is responsible for coordinating and supervising staff and consulting engineers of the company in ongoing reservoir evaluation studies worldwide. Before joining Ryder Scott, Mr. Ramirez served in a number of engineering positions with Sun Oil Company and Natomas North America. For more information regarding Mr. Ramirez’s geographic and job specific experience, please refer to the Ryder Scott Company website at www.ryderscott.com/Company/Employees.

Mr. Ramirez earned a Bachelor of Science Degree in Mechanical Engineering with honors from Texas A&M University in 1976 and is a licensed Professional Engineer in the State of Texas. He is also a member of the Society of Petroleum Engineers and Society of Petroleum Evaluation Engineers.

In addition to gaining experience and competency through prior work experience, the Texas Board of Professional Engineers requires a minimum of fifteen hours of continuing education annually, including at least one hour in the area of professional ethics, which Mr. Ramirez fulfills. As part of his 2017 continuing education hours, Mr. Ramirez attended and internally received 12 hours of formalized training as well as a day-long public forum, the 2017 RSC Reserves Conference relating to the definitions and disclosure guidelines contained in the United States Securities and Exchange Commission Title 17, Code of Federal Regulations, Modernization of Oil and Gas Reporting, Final Rule released January 14, 2009 in the Federal Register. Mr. Ramirez has also presented courses on the new SEC and SPE-PRMS reserves definitions on various occasions during 2011, 2012, 2013, 2015 and 2017 and received 7.0 hours of formalized external training during 2017, covering such topics as the Guidelines for Application of the SPE/WPC/AAPG/SPEE Petroleum Resources Management System, reservoir engineering, geoscience and petroleum economics evaluation methods, procedures and software, unconventional resources and ethics for consultants.

Based on his educational background, professional training and more than 35 years of practical experience in the estimation and evaluation of petroleum reserves, Mr. Ramirez has attained the professional qualifications as a Reserves Estimator and Reserves Auditor set forth in Article III of the “Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information” promulgated by the Society of Petroleum Engineers as of February 19, 2007.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

PETROLEUM RESERVES DEFINITIONS

As Adapted From:

RULE 4-10(a) of REGULATION S-X PART 210

UNITED STATES SECURITIES AND EXCHANGE COMMISSION (SEC)

PREAMBLE

On January 14, 2009, the United States Securities and Exchange Commission (SEC) published the “Modernization of Oil and Gas Reporting; Final Rule” in the Federal Register of National Archives and Records Administration (NARA). The “Modernization of Oil and Gas Reporting; Final Rule” includes revisions and additions to the definition section in Rule 4-10 of Regulation S-X, revisions and additions to the oil and gas reporting requirements in Regulation S-K, and amends and codifies Industry Guide 2 in Regulation S-K. The “Modernization of Oil and Gas Reporting; Final Rule”, including all references to Regulation S-X and Regulation S-K, shall be referred to herein collectively as the “SEC regulations”. The SEC regulations take effect for all filings made with the United States Securities and Exchange Commission as of December 31, 2009, or after January 1, 2010. Reference should be made to the full text under Title 17, Code of Federal Regulations, Regulation S-X Part 210, Rule 4-10(a) for the complete definitions (direct passages excerpted in part or wholly from the aforementioned SEC document are denoted in italics herein).

Reserves are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. All reserve estimates involve an assessment of the uncertainty relating the likelihood that the actual remaining quantities recovered will be greater or less than the estimated quantities determined as of the date the estimate is made. The uncertainty depends chiefly on the amount of reliable geologic and engineering data available at the time of the estimate and the interpretation of these data. The relative degree of uncertainty may be conveyed by placing reserves into one of two principal classifications, either proved or unproved. Unproved reserves are less certain to be recovered than proved reserves and may be further sub-classified as probable and possible reserves to denote progressively increasing uncertainty in their recoverability. Under the SEC regulations as of December 31, 2009, or after January 1, 2010, a company may optionally disclose estimated quantities of probable or possible oil and gas reserves in documents publicly filed with the SEC. The SEC regulations continue to prohibit disclosure of estimates of oil and gas resources other than reserves and any estimated values of such resources in any document publicly filed with the SEC unless such information is required to be disclosed in the document by foreign or state law as noted in §229.1202 Instruction to Item 1202.

Reserves estimates will generally be revised only as additional geologic or engineering data become available or as economic conditions change.

Reserves may be attributed to either natural energy or improved recovery methods. Improved recovery methods include all methods for supplementing natural energy or altering natural forces in the reservoir to increase ultimate recovery. Examples of such methods are pressure maintenance, natural gas cycling, waterflooding, thermal methods, chemical flooding, and the use of miscible and immiscible displacement fluids. Other improved recovery methods may be developed in the future as petroleum technology continues to evolve.

Reserves may be attributed to either conventional or unconventional petroleum accumulations. Petroleum accumulations are considered as either conventional or unconventional based on the nature of their in-place characteristics, extraction method applied, or degree of processing prior to sale.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

PETROLEUM RESERVES DEFINITIONS

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Examples of unconventional petroleum accumulations include coalbed or coalseam methane (CBM/CSM), basin-centered gas, shale gas, gas hydrates, natural bitumen and oil shale deposits. These unconventional accumulations may require specialized extraction technology and/or significant processing prior to sale.

Reserves do not include quantities of petroleum being held in inventory.

Because of the differences in uncertainty, caution should be exercised when aggregating quantities of petroleum from different reserves categories.

RESERVES (SEC DEFINITIONS)

Securities and Exchange Commission Regulation S-X §210.4-10(a)(26) defines reserves as follows:

Reserves. Reserves are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and gas or related substances to market, and all permits and financing required to implement the project.

Note to paragraph (a)(26): Reserves should not be assigned to adjacent reservoirs isolated by major, potentially sealing, faults until those reservoirs are penetrated and evaluated as economically producible. Reserves should not be assigned to areas that are clearly separated from a known accumulation by a non-productive reservoir (i.e., absence of reservoir, structurally low reservoir, or negative test results). Such areas may contain prospective resources (i.e., potentially recoverable resources from undiscovered accumulations).

PROVED RESERVES (SEC DEFINITIONS)

Securities and Exchange Commission Regulation S-X §210.4-10(a)(22) defines proved oil and gas reserves as follows:

Proved oil and gas reserves. Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.

(i) The area of the reservoir considered as proved includes:

(A) The area identified by drilling and limited by fluid contacts, if any, and

(B) Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

PETROLEUM RESERVES DEFINITIONS

Page 3

PROVED RESERVES (SEC DEFINITIONS) CONTINUED

(ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty.

(iii) Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty.

(iv) Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when:

(A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and

(B) The project has been approved for development by all necessary parties and entities, including governmental entities.

(v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

PETROLEUM RESERVES STATUS DEFINITIONS AND GUIDELINES

As Adapted From:

RULE 4-10(a) of REGULATION S-X PART 210

UNITED STATES SECURITIES AND EXCHANGE COMMISSION (SEC)

and

PETROLEUM RESOURCES MANAGEMENT SYSTEM (SPE-PRMS)

Sponsored and Approved by:

SOCIETY OF PETROLEUM ENGINEERS (SPE)

WORLD PETROLEUM COUNCIL (WPC)

AMERICAN ASSOCIATION OF PETROLEUM GEOLOGISTS (AAPG)

SOCIETY OF PETROLEUM EVALUATION ENGINEERS (SPEE)

Reserves status categories define the development and producing status of wells and reservoirs. Reference should be made to Title 17, Code of Federal Regulations, Regulation S-X Part 210, Rule 4-10(a) and the SPE-PRMS as the following reserves status definitions are based on excerpts from the original documents (direct passages excerpted from the aforementioned SEC and SPE-PRMS documents are denoted in italics herein).

DEVELOPED RESERVES (SEC DEFINITIONS)

Securities and Exchange Commission Regulation S-X §210.4-10(a)(6) defines developed oil and gas reserves as follows:

Developed oil and gas reserves are reserves of any category that can be expected to be recovered:

(i) Through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and

(ii) Through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well.

Developed Producing (SPE-PRMS Definitions)

While not a requirement for disclosure under the SEC regulations, developed oil and gas reserves may be further sub-classified according to the guidance contained in the SPE-PRMS as Producing or Non-Producing.

Developed Producing Reserves

Developed Producing Reserves are expected to be recovered from completion intervals that are open and producing at the time of the estimate.

Improved recovery reserves are considered producing only after the improved recovery project is in operation.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

PETROLEUM RESERVES STATUS DEFINITIONS AND GUIDELINES

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Developed Non-Producing

Developed Non-Producing Reserves include shut-in and behind-pipe reserves.

Shut-In

Shut-in Reserves are expected to be recovered from:

(1) completion intervals which are open at the time of the estimate, but which have not started producing;

(2) wells which were shut-in for market conditions or pipeline connections; or

(3) wells not capable of production for mechanical reasons.

Behind-Pipe

Behind-pipe Reserves are expected to be recovered from zones in existing wells, which will require additional completion work or future re-completion prior to start of production.

In all cases, production can be initiated or restored with relatively low expenditure compared to the cost of drilling a new well.

UNDEVELOPED RESERVES (SEC DEFINITIONS)

Securities and Exchange Commission Regulation S-X §210.4-10(a)(31) defines undeveloped oil and gas reserves as follows:

Undeveloped oil and gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion.

(i) Reserves on undrilled acreage shall be limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances.

(ii) Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances, justify a longer time.

(iii) Under no circumstances shall estimates for undeveloped reserves be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, as defined in paragraph (a)(2) of this section, or by other evidence using reliable technology establishing reasonable certainty.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

Exhibit 10.2

(Part 2 of 2)

Pemex Exploración y Producción

Estimated

Future Reserves

Attributable to Certain

Oil and Gas Properties in Mexico

Activo Bellota-Jujo

Activo Cinco Presidentes

Activo Macuspana-Muspac

Activo Samaria-Luna

SEC Parameters

As of

December 31, 2017

Guale Ramirez, P.E.

TBPE License No.48318

Executive Vice President

RYDER SCOTT COMPANY, L.P.

TBPE Firm Registration No. F-1580

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

TBPE REGISTERED ENGINEERING FIRM F-1580		FAX (713) 651-0849
1100 LOUISIANA SUITE 4600	HOUSTON, TEXAS 77002-5294	TELEPHONE (713) 651-9191

April 20, 2018

Ing. J. Javier Hinojosa Puebla

Director General de Pemex Exploración y Producción

Avenida Marina Nacional 329

Torre Ejecutiva, Piso 41

Col Verónica Anzures, C.P. 11300

Del. Miguel Hidalgo, Ciudad de México

México

Dear Ing. Hinojosa Puebla:

At the request of Pemex Exploración y Producción (PEP), a wholly owned subsidiary of Petróleos Mexicanos (Pemex), Ryder Scott Company, L.P. (Ryder Scott) has conducted a reserves audit of the estimates of the proved reserves owned by the United Mexican States as of December 31, 2017. In most cases the properties reviewed by us are operated by Pemex; however, certain contract areas are operated by other companies. The estimates we audited were prepared by PEP’s engineering and geological staff based on the definitions and disclosure guidelines of the United States Securities and Exchange Commission contained in Title 17, Code of Federal Regulations, Modernization of Oil and Gas Reporting, Final Rule released January 14, 2009, in the Federal Register (SEC regulations). Our third party reserves audit, completed on February 28, 2018, and presented herein, was prepared for public disclosure by Pemex in filings made with the SEC in accordance with the disclosure requirements set forth in the SEC regulations. The properties reviewed by Ryder Scott in this report are comprised of those properties contractually awarded to PEP and located in four areas of operations known as Activos. The names of these Activos as well as their geographical locations are shown below:

Activo Bellota-Jujo	Onshore Mexican state of Tabasco
Activo Cinco Presidentes	Onshore Mexican states of Tabasco and Veracruz
Activo Macuspana-Muspac	Onshore Mexican states of Chiapas and Tabasco
Activo Samaria-Luna	Onshore Mexican state of Tabasco

The proved net reserves attributable to the properties that we reviewed account for 100 percent of the total proved net oil equivalent barrels (BOE) of PEP for the Activos listed above.

As prescribed by the Society of Petroleum Engineers in Paragraph 2.2(f) of the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information (SPE auditing standards), a reserves audit is defined as “the process of reviewing certain of the pertinent facts interpreted and assumptions made that have resulted in an estimate of reserves and/or Reserves Information prepared by others and the rendering of an opinion about (1) the appropriateness of the methodologies employed; (2) the adequacy and quality of the data relied upon; (3) the depth and thoroughness of the reserves estimation process; (4) the classification of reserves appropriate to the relevant definitions used; and (5) the reasonableness of the estimated reserve quantities and/or Reserves Information.” Reserves Information may consist of various estimates pertaining to the extent and value of petroleum properties.

SUITE 800, 350 7TH AVENUE, S.W.	CALGARY, ALBERTA T2P 3N9	TEL (403) 262-2799	FAX (403) 262-2790
621 17TH STREET, SUITE 1550	DENVER, COLORADO 80293-1501	TEL (303) 623-9147	FAX (303) 623-4258

Pemex Exploración y Producción

April 20, 2018

Page 2

Based on our review, including the data, technical processes and interpretations presented by PEP, it is our opinion that the overall procedures and methodologies utilized by PEP in preparing their estimates of the proved reserves as of December 31, 2017 comply with the current SEC regulations, and that the overall proved reserves for the reviewed properties as estimated by PEP are, in the aggregate, reasonable within the established audit tolerance guidelines of 10 percent set forth in the SPE auditing standards.

The estimated reserves presented in this report are related to hydrocarbon prices. PEP has informed us that in the preparation of their reserve and income projections, as of December 31, 2017, they used average prices during the 12-month period prior to the “as of date” of this report, determined as the unweighted arithmetic averages of the prices in effect on the first-day-of-the-month for each month within such period, unless prices were defined by contractual arrangements, as required by the SEC regulations. Actual future prices may vary significantly from the prices required by SEC regulations; therefore, volumes of reserves actually recovered may differ significantly from the estimated quantities presented in this report. The net reserves as estimated by PEP attributable to the properties that we reviewed are summarized below:

SEC PARAMETERS

Estimated Net Reserves

Attributable to Certain Properties

Bellota Jujo – Cinco Presidentes – Macuspana Muspac – Samaria Luna

As of December 31, 2017

	Proved
	Developed						Total
	Producing		Non-Producing		Undeveloped		Proved
Net Reserves of Properties
Audited by Ryder Scott
Oil/Condensate – MM Barrels		265.1		184.4		219.3		668.8
Plant Products(1) – MM Barrels		73.3		50.2		58.8		182.3
Dry Gas(2) – MM Barrels Equivalent		131.7		88.2		103.4		323.4
BOE(3) – MM Barrels		470.2		322.9		381.5		1,174.5	(5)
Gross Gas(4) – MMMCF		897.0		618.2		698.4		2,213.6	(5)

(1) Includes liquids generated through the transportation process and at the petrochemical plants.

(2) Dry Gas reserves are the dry, sweetened gas available for sale by Pemex - Gas y Petroquímica Básica at the tailgate of the processing plants.

(3) Barrels of oil-equivalent are based on dry gas conversion factors provided by PEP.

(4) Gross Gas represents produced volumes of gas before any losses for fuel use, venting, transporting or plant shrinkage.

(5) May not match the sum of the reserves sub-classes exactly due to rounding.

Liquid hydrocarbons are expressed in standard 42 gallon barrels and are shown in millions of barrels (MM Barrels). All gas volumes are reported on an “as-sold” basis expressed in billions of cubic feet (MMMCF) at the official temperature and pressure bases of the areas in which the gas reserves are located. The net remaining reserves are also shown herein on an equivalent unit (BOE) basis wherein natural gas is converted to oil equivalent barrels using a specific factor for each field. MMBOE represents million barrels of oil equivalent.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

Pemex Exploración y Producción

April 20, 2018

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Reserves Included in This Report

In our opinion, the proved reserves reviewed by us and presented in this report conform to the definition as set forth in the Securities and Exchange Commission’s Regulations Part 210.4-10(a). An abridged version of the SEC reserves definitions from 210.4-10(a) entitled “Petroleum Reserves Definitions” is included as an attachment to this report.

The various proved reserve status categories are defined under the attachment entitled “Petroleum Reserves Status Definitions and Guidelines” in this report. The proved developed non-producing reserves included herein consist of the shut-in and behind pipe categories.

Reserves are “estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations.” All reserve estimates involve an assessment of the uncertainty relating the likelihood that the actual remaining quantities recovered will be greater or less than the estimated quantities determined as of the date the estimate is made. The uncertainty depends chiefly on the amount of reliable geologic and engineering data available at the time of the estimate and the interpretation of these data. The relative degree of uncertainty may be conveyed by placing reserves into one of two principal categories, either proved or unproved. Unproved reserves are less certain to be recovered than proved reserves and may be further sub-categorized as probable and possible reserves to denote progressively increasing uncertainty in their recoverability. At PEP’s request, this report addresses only the proved reserves attributable to the properties reviewed herein.

Proved oil and gas reserves are those quantities of oil and gas which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward.” The proved reserves included herein were estimated using deterministic methods. If deterministic methods are used, the SEC has defined reasonable certainty for proved reserves as a “high degree of confidence that the quantities will be recovered.”

Proved reserve estimates will generally be revised only as additional geologic or engineering data become available or as economic conditions change. For proved reserves, the SEC states that “as changes due to increased availability of geoscience (geological, geophysical, and geochemical), engineering, and economic data are made to the estimated ultimate recovery (EUR) with time, reasonably certain EUR is much more likely to increase or remain constant than to decrease.” Moreover, estimates of proved reserves may be revised as a result of future operations, effects of regulation by governmental agencies or geopolitical or economic risks. Therefore, the proved reserves included in this report are estimates only and should not be construed as being exact quantities, and if recovered, could be more or less than the estimated amounts.

Audit Data, Methodology, Procedure and Assumptions

The estimation of reserves involves two distinct determinations. The first determination results in the estimation of the quantities of recoverable oil and gas and the second determination results in the estimation of the uncertainty associated with those estimated quantities in accordance with the definitions set forth by the Securities and Exchange Commission’s Regulations Part 210.4-10(a). The process of estimating the quantities of recoverable oil and gas reserves relies on the use of certain generally accepted analytical procedures. These analytical procedures fall into three broad categories or methods: (1) performance-based methods; (2) volumetric-based methods; and (3) analogy. These methods may be used individually or in combination by the reserve evaluator in the process of estimating the quantities of reserves. Reserve evaluators must select the method or combination of

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

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methods that in their professional judgment is most appropriate given the nature and amount of reliable geoscience and engineering data available at the time of the estimate, the established or anticipated performance characteristics of the reservoir being evaluated and the stage of development or producing maturity of the property.

In many cases, the analysis of the available geoscience and engineering data and the subsequent interpretation of this data may indicate a range of possible outcomes in an estimate, irrespective of the method selected by the evaluator. When a range in the quantity of reserves is identified, the evaluator must determine the uncertainty associated with the incremental quantities of the reserves. If the reserve quantities are estimated using the deterministic incremental approach, the uncertainty for each discrete incremental quantity of the reserves is addressed by the reserve category assigned by the evaluator. Therefore, it is the categorization of reserve quantities as proved, probable and/or possible that addresses the inherent uncertainty in the estimated quantities reported. For proved reserves, uncertainty is defined by the SEC as reasonable certainty wherein the “quantities actually recovered are much more likely than not to be achieved.” The SEC states that “probable reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered.” The SEC states that “possible reserves are those additional reserves that are less certain to be recovered than probable reserves and the total quantities ultimately recovered from a project have a low probability of exceeding proved plus probable plus possible reserves.” All quantities of reserves within the same reserve category must meet the SEC definitions as noted above.

Estimates of reserves quantities and their associated reserve categories may be revised in the future as additional geoscience or engineering data become available. Furthermore, estimates of reserves quantities and their associated reserve categories may also be revised due to other factors such as changes in economic conditions, results of future operations, effects of regulation by governmental agencies or geopolitical or economic risks as previously noted herein.

The proved reserves prepared by PEP for the properties that we reviewed were estimated by performance methods, the volumetric method, analogy, or a combination of methods. Approximately 90 percent of the proved producing reserves attributable to producing wells and/or reservoirs that we reviewed were estimated by performance methods. These performance methods include, but may not be limited to, decline curve analysis, numerical simulation and material balance calculations, which utilized extrapolations of historical production and pressure data available through December 2017, in those cases where such data were considered to be definitive. The data utilized in these analyses were furnished to Ryder Scott by PEP and were considered sufficient for the purpose thereof. The remaining 10 percent of the proved producing reserves that we reviewed were estimated by the volumetric method, analogy, or a combination of methods. These methods were used where there were inadequate historical performance data to establish a definitive trend and where the use of production performance data as a basis for the reserve estimates was considered to be inappropriate.

All of the proved developed non-producing and undeveloped reserves that we reviewed were estimated by the volumetric method, analogy, or a combination of methods. The volumetric analyses utilized pertinent well and seismic data furnished to Ryder Scott by PEP for our review that were available through December 2017. The data utilized from the analogues in conjunction with well and seismic data incorporated into the volumetric analysis were considered sufficient for the purpose thereof.

To estimate economically recoverable proved oil and gas reserves many factors and assumptions are considered including, but not limited to, the use of reservoir parameters derived from geological, geophysical and engineering data which cannot be measured directly, economic criteria

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

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based on current costs and SEC pricing requirements, and forecasts of future production rates. Under the SEC regulations 210.4-10(a)(22)(v) and (26), proved reserves must be anticipated to be economically producible from a given date forward based on existing economic conditions including the prices and costs at which economic producibility from a reservoir is to be determined. While it may reasonably be anticipated that the future prices received for the sale of production and the operating costs and other costs relating to such production may increase or decrease from those under existing economic conditions, such changes were, in accordance with rules adopted by the SEC, omitted from consideration in conducting this review.

As stated previously, proved reserves must be anticipated to be economically producible from a given date forward based on existing economic conditions including the prices and costs at which economic producibility from a reservoir is to be determined. To confirm that the proved reserves reviewed by us meet the SEC requirements to be economically producible, we have reviewed certain primary economic data utilized by PEP relating to hydrocarbon prices and costs as noted herein.

The hydrocarbon prices furnished by PEP for the properties reviewed by us are based on SEC price parameters using the average prices during the 12-month period prior to the “as of date” of this report, determined as the unweighted arithmetic averages of the prices in effect on the first-day-of-the-month for each month within such period, unless prices were defined by contractual arrangements. For hydrocarbon products sold under contract, the contract prices, including fixed and determinable escalations exclusive of inflation adjustments, were used until expiration of the contract. Upon contract expiration, the prices were adjusted to the 12-month unweighted arithmetic average as previously described.

The initial SEC hydrocarbon prices in effect on December 31, 2017 for the properties reviewed by us were determined using the 12-month average first-day-of-the-month prices appropriate to the geographic areas where the hydrocarbons are sold. These prices are the actual prices received by PEP for the sale of hydrocarbon products to its affiliates such as Pemex - Refinación.

The table below summarizes PEP’s net volume weighted prices adjusted for differentials for the properties reviewed by us by geographic areas and referred to herein as PEP’s “average realized prices.” The average realized prices shown in the table below were determined from PEP’s estimate of the total future gross revenue before production taxes for the properties reviewed by us and PEP’s estimate of the total net reserves for the properties reviewed by us for each of the areas referred to as Activos as listed below. The data shown in the table below is presented in accordance with SEC disclosure requirements for each of the geographic areas shown and reviewed by us.

Geographic Area (Activo)	Product		Average Realized Prices
Bellota-Jujo		Oil/Condensate	$	54.95/Bbl
		Gas	$	4.24/MCF
Cinco Presidentes		Oil/Condensate	$	53.78/Bbl
		Gas	$	5.31/MCF
Macuspana-Muspac		Oil/Condensate	$	57.23/Bbl
		Gas	$	4.12/MCF
Samaria-Luna		Oil/Condensate	$	55.67/Bbl
		Gas	$	4.18/MCF

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

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April 20, 2018

Page 6

The effects of derivative instruments designated as price hedges of oil and gas quantities are not reflected in PEP’s individual property evaluations.

Accumulated gas production imbalances, if any, were not taken into account in the proved gas reserve estimates reviewed. The proved gas volumes included herein do not attribute gas consumed in operations as reserves.

Operating costs furnished by PEP are based on the operating expense reports of PEP and include only those costs directly applicable to the fields or wells for the properties reviewed by us. The operating costs include a portion of general and administrative costs allocated directly to the fields and wells. The operating costs furnished by PEP were accepted as factual data and reviewed by us for their reasonableness; however, we have not conducted an independent verification of the data used by PEP. No deduction was made for loan repayments, interest expenses, or exploration and development prepayments that were not charged directly to the fields, wells or contract areas.

Development costs furnished by PEP are based on authorizations for expenditure for the proposed work or actual costs for similar projects. The development costs furnished by PEP were accepted as factual data and reviewed by us for their reasonableness; however, we have not conducted an independent verification of the data used by PEP. The estimated net cost of abandonment after salvage was included by Pemex for properties where abandonment costs net of salvage were significant. Pemex’s estimates of the net abandonment costs were accepted without independent verification.

The proved developed non-producing and undeveloped reserves for the operated and non-operated properties reviewed by us have been incorporated herein in accordance with PEP’s and the other operator’s plans to develop these reserves as of December 31, 2017. The implementation of these development plans as presented to us is subject to the approval process adopted by PEP’s management. As the result of our inquiries during the course of our review, PEP has informed us that the development activities for the properties reviewed by us have been subjected to and received the internal approvals required by PEP’s management at the appropriate local, regional and/or corporate level. PEP has also informed us that the same type of approval process has been conducted by the other operators for those properties that such companies operate. Additionally, PEP has informed us that they are not aware of any legal, regulatory or political obstacles that would significantly alter their plans. While these plans could change from those under existing economic conditions as of December 31, 2017, such changes were, in accordance with rules adopted by the SEC, omitted from consideration in making this evaluation.

Current costs used by PEP were held constant throughout the life of the properties.

As previously stated, certain properties that we reviewed are situated in contract areas that are not operated by PEP. According to the new Mexican hydrocarbon law, these companies have the option to convert the contractual terms currently in place to other types of contractual arrangements such as Concession Licenses, Production Sharing Contracts or Profit Sharing Contracts. Currently Pemex has entered into such a contractual agreement with one company on three specific fields and the net reserves pertaining to PEP for these fields have been included in the reserves stated above. Other negotiations currently or soon to be in progress are not in effect as of the effective date of this report. Therefore, the reserves reported herein for these areas are based on the contractual terms that were effective as of December 31, 2017.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

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PEP’s forecasts of future production rates are based on historical performance from wells currently on production. If no production decline trend has been established, future production rates were held constant until a decline in ability to produce was anticipated. An estimated rate of decline was then applied to depletion of the reserves. If a decline trend has been established, this trend was used as the basis for estimating future production rates.

Test data and other related information were used by PEP to estimate the anticipated initial production rates for those wells or locations that are not currently producing. For reserves not yet on production, sales were estimated to commence at an anticipated date furnished by PEP. Wells or locations that are not currently producing may start producing earlier or later than anticipated in PEP’s estimates due to unforeseen factors causing a change in the timing to initiate production. Such factors may include delays due to weather, the availability of rigs, the sequence of drilling, completing and/or recompleting wells and/or constraints set by regulatory bodies.

The future production rates from wells currently on production or wells or locations that are not currently producing may be more or less than estimated because of changes including, but not limited to, reservoir performance, operating conditions related to surface facilities, compression and artificial lift, pipeline capacity and/or operating conditions, producing market demand and/or allowables or other constraints set by regulatory bodies.

Ryder Scott did not evaluate the country and geopolitical risks in the country of Mexico where all of the subject properties are located. PEP’s operations and the operations of the other companies may be subject to various levels of governmental controls and regulations. These controls and regulations may include, but may not be limited to, matters relating to land tenure and use, drilling and production practices, environmental protection, marketing and pricing policies, various taxes and levies and are subject to change from time to time. Such changes in governmental regulations and policies may cause volumes of proved reserves actually recovered and amounts of proved income actually received to differ significantly from the estimated quantities.

Certain properties included herein are operated by other operators under specified operating contracts. Under the terms of these contracts, the other operators have the right to operate and produce hydrocarbons; however, the produced volumes are ultimately delivered to PEP for marketing. Such contracts signed between PEP and the other operators also dictate that the reserves associated with the contract areas are the property of the United Mexican States.

The estimates of proved reserves presented herein were based upon a review of the subject properties; however, we have not made any field examination of the properties. No consideration was given in this report to potential environmental liabilities that may exist nor were any costs included by PEP for potential liabilities to restore and clean up damages, if any, caused by past operating practices.

Certain technical personnel of PEP are responsible for the preparation of reserve estimates on new properties and for the preparation of revised estimates, when necessary, on old properties. These personnel assembled the necessary data and maintained the data and workpapers in an orderly manner. We consulted with these technical personnel and had access to their workpapers and supporting data in the course of our audit.

PEP has informed us that for both the operated and non-operated properties they have furnished us all of the material accounts, records, geological and engineering data, and reports and other data required for this investigation. In performing our audit of PEP’s forecast of future proved production, we have relied upon data furnished by PEP with respect to property interests, production and well tests from examined wells, normal direct costs of operating the properties, other costs such as transportation and/or processing fees, recompletion and development costs, development plans, abandonment costs after salvage, product prices based on the SEC regulations, adjustments or

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differentials to product prices, geological structural and isochore maps, well logs, core analyses, and pressure measurements. For non-operated properties, the costs provided by Pemex include all charges related to the expense of such contractual obligations. Ryder Scott reviewed such factual data for its reasonableness; however, we have not conducted an independent verification of the data furnished by PEP. The data described herein were accepted as authentic and sufficient for determining the reserves unless, during the course of our examination, a matter of question came to our attention in which case the data were not accepted until all questions were satisfactorily resolved. We consider the factual data furnished to us by PEP to be appropriate and sufficient for the purpose of our review of PEP’s estimates of reserves. In summary, we consider the assumptions, data, methods and analytical procedures used by PEP and as reviewed by us appropriate for the purpose hereof, and we have used all such methods and procedures that we consider necessary and appropriate under the circumstances to render the conclusions set forth herein.

Audit Opinion

Based on our review, including the data, technical processes and interpretations presented by PEP, it is our opinion that the overall procedures and methodologies utilized by PEP in preparing their estimates of the proved reserves as of December 31, 2017 comply with the current SEC regulations and that the overall proved reserves in terms of barrels of oil equivalent (BOE) for the reviewed properties as estimated by PEP are, in the aggregate, reasonable within the established audit tolerance guidelines of 10 percent as set forth in the SPE auditing standards. Ryder Scott found the processes and controls used by PEP in their estimation of proved reserves to be effective and, in the aggregate, we found no bias in the utilization and analysis of data in estimates for these properties.

We were in reasonable agreement with PEP’s estimates of proved reserves for the properties which we reviewed; however, in certain cases there was more than an acceptable variance between PEP’s estimates and our estimates due to a difference in interpretation of data or due to our having access to data which were not available to PEP when its reserve estimates were prepared. In these cases, PEP revised its estimates to better conform to our estimates. As a consequence, it is our opinion that on an aggregate basis the data presented herein for the properties that we reviewed fairly reflects the estimated net reserves for those properties, both operated and non-operated, and owned by the United Mexican States.

Standards of Independence and Professional Qualification

Ryder Scott is an independent petroleum engineering consulting firm that has been providing petroleum consulting services throughout the world since 1937. Ryder Scott is employee-owned and maintains offices in Houston, Texas; Denver, Colorado; and Calgary, Alberta, Canada. We have over eighty engineers and geoscientists on our permanent staff. By virtue of the size of our firm and the large number of clients for which we provide services, no single client or job represents a material portion of our annual revenue. We do not serve as officers or directors of any privately-owned or publicly-traded oil and gas company and are separate and independent from the operating and investment decision-making process of our clients. This allows us to bring the highest level of independence and objectivity to each engagement for our services.

Ryder Scott actively participates in industry-related professional societies and organizes an annual public forum focused on the subject of reserves evaluations and SEC regulations. Many of our staff have authored or co-authored technical papers on the subject of reserves related topics. We encourage our staff to maintain and enhance their professional skills by actively participating in ongoing continuing education.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

Pemex Exploración y Producción

April 20, 2018

Page 9

Prior to becoming an officer of the Company, Ryder Scott requires that staff engineers and geoscientists have received professional accreditation in the form of a registered or certified professional engineer’s license or a registered or certified professional geoscientist’s license, or the equivalent thereof, from an appropriate governmental authority or a recognized self-regulating professional organization.

We are independent petroleum engineers with respect to PEP. Neither we nor any of our employees have any financial interest in the subject properties, and neither the employment to do this work nor the compensation is contingent on our estimates of reserves for the properties which were reviewed.

The results of this audit, presented herein, are based on technical analysis conducted by teams of geoscientists and engineers from Ryder Scott. The professional qualifications of the undersigned, the technical person primarily responsible for the review of the reserves information discussed in this report, are included as an attachment to this letter.

Terms of Usage

The results of our third party audit, presented in report form herein, were prepared in accordance with the disclosure requirements set forth in the SEC regulations and intended for public disclosure as an exhibit in filings made with the SEC by Pemex.

Pemex makes periodic filings on Form 20-F with the SEC under the 1934 Exchange Act. Furthermore, Pemex files registration statements with the SEC under the 1933 Securities Act into which filings on Form 20-F are incorporated by reference. We have consented to the references to our name in and the filing of this report as an exhibit to the annual report on Form 20-F of Pemex for the year ended December 31, 2017 Our written consent for such use will be included as a separate exhibit to such Form 20-F. In the event the references to our name as well as references to our report are incorporated by reference into any registration statement on Form F-4, then our written consent for such use will be included as a separate exhibit to such registration statement.

We have provided PEP with a digital version of the original signed copy of this report letter. In the event there are any differences between the digital version included in filings made by Pemex and the original signed report letter, the original signed report letter shall control and supersede the digital version.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

Pemex Exploración y Producción

April 20, 2018

Page 10

The data and workpapers used in the preparation of this report are available for examination by authorized parties in our offices. Please contact us if we can be of further service.

	Very truly yours, RYDER SCOTT COMPANY, L.P. TBPE Firm Registration No. F-1580 Guale Ramirez, P.E. TBPE License No. 48318 Executive Vice President
GR (DPR)/pl

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

Professional Qualifications of Primary Technical Person

The conclusions presented in this report are the result of technical analysis conducted by teams of geoscientists and engineers from Ryder Scott Company, L.P. Guadalupe Ramirez was the primary technical person responsible for overseeing the estimate of the reserves, future production and income.

Mr. Ramirez, an employee of Ryder Scott Company, L.P. (Ryder Scott) since 1981, is the Executive Vice President and also serves as a member of the Board of Directors. He is responsible for coordinating and supervising staff and consulting engineers of the company in ongoing reservoir evaluation studies worldwide. Before joining Ryder Scott, Mr. Ramirez served in a number of engineering positions with Sun Oil Company and Natomas North America. For more information regarding Mr. Ramirez’s geographic and job specific experience, please refer to the Ryder Scott Company website at www.ryderscott.com/Company/Employees.

Mr. Ramirez earned a Bachelor of Science Degree in Mechanical Engineering with honors from Texas A&M University in 1976 and is a licensed Professional Engineer in the State of Texas. He is also a member of the Society of Petroleum Engineers and Society of Petroleum Evaluation Engineers.

In addition to gaining experience and competency through prior work experience, the Texas Board of Professional Engineers requires a minimum of fifteen hours of continuing education annually, including at least one hour in the area of professional ethics, which Mr. Ramirez fulfills. As part of his 2017 continuing education hours, Mr. Ramirez attended and internally received 12 hours of formalized training as well as a day-long public forum, the 2017 RSC Reserves Conference relating to the definitions and disclosure guidelines contained in the United States Securities and Exchange Commission Title 17, Code of Federal Regulations, Modernization of Oil and Gas Reporting, Final Rule released January 14, 2009 in the Federal Register. Mr. Ramirez has also presented courses on the new SEC and SPE-PRMS reserves definitions on various occasions during 2011, 2012, 2013, 2015 and 2017 and received 7.0 hours of formalized external training during 2017, covering such topics as the Guidelines for Application of the SPE/WPC/AAPG/SPEE Petroleum Resources Management System, reservoir engineering, geoscience and petroleum economics evaluation methods, procedures and software, unconventional resources and ethics for consultants.

Based on his educational background, professional training and more than 35 years of practical experience in the estimation and evaluation of petroleum reserves, Mr. Ramirez has attained the professional qualifications as a Reserves Estimator and Reserves Auditor set forth in Article III of the “Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information” promulgated by the Society of Petroleum Engineers as of February 19, 2007.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

PETROLEUM RESERVES DEFINITIONS

As Adapted From:

RULE 4-10(a) of REGULATION S-X PART 210

UNITED STATES SECURITIES AND EXCHANGE COMMISSION (SEC)

PREAMBLE

On January 14, 2009, the United States Securities and Exchange Commission (SEC) published the “Modernization of Oil and Gas Reporting; Final Rule” in the Federal Register of National Archives and Records Administration (NARA). The “Modernization of Oil and Gas Reporting; Final Rule” includes revisions and additions to the definition section in Rule 4-10 of Regulation S-X, revisions and additions to the oil and gas reporting requirements in Regulation S-K, and amends and codifies Industry Guide 2 in Regulation S-K. The “Modernization of Oil and Gas Reporting; Final Rule”, including all references to Regulation S-X and Regulation S-K, shall be referred to herein collectively as the “SEC regulations”. The SEC regulations take effect for all filings made with the United States Securities and Exchange Commission as of December 31, 2009, or after January 1, 2010. Reference should be made to the full text under Title 17, Code of Federal Regulations, Regulation S-X Part 210, Rule 4-10(a) for the complete definitions (direct passages excerpted in part or wholly from the aforementioned SEC document are denoted in italics herein).

Reserves are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. All reserve estimates involve an assessment of the uncertainty relating the likelihood that the actual remaining quantities recovered will be greater or less than the estimated quantities determined as of the date the estimate is made. The uncertainty depends chiefly on the amount of reliable geologic and engineering data available at the time of the estimate and the interpretation of these data. The relative degree of uncertainty may be conveyed by placing reserves into one of two principal classifications, either proved or unproved. Unproved reserves are less certain to be recovered than proved reserves and may be further sub-classified as probable and possible reserves to denote progressively increasing uncertainty in their recoverability. Under the SEC regulations as of December 31, 2009, or after January 1, 2010, a company may optionally disclose estimated quantities of probable or possible oil and gas reserves in documents publicly filed with the SEC. The SEC regulations continue to prohibit disclosure of estimates of oil and gas resources other than reserves and any estimated values of such resources in any document publicly filed with the SEC unless such information is required to be disclosed in the document by foreign or state law as noted in §229.1202 Instruction to Item 1202.

Reserves estimates will generally be revised only as additional geologic or engineering data become available or as economic conditions change.

Reserves may be attributed to either natural energy or improved recovery methods. Improved recovery methods include all methods for supplementing natural energy or altering natural forces in the reservoir to increase ultimate recovery. Examples of such methods are pressure maintenance, natural gas cycling, waterflooding, thermal methods, chemical flooding, and the use of miscible and immiscible displacement fluids. Other improved recovery methods may be developed in the future as petroleum technology continues to evolve.

Reserves may be attributed to either conventional or unconventional petroleum accumulations. Petroleum accumulations are considered as either conventional or unconventional based on the nature of their in-place characteristics, extraction method applied, or degree of processing prior to sale.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

PETROLEUM RESERVES DEFINITIONS

Page 2

Examples of unconventional petroleum accumulations include coalbed or coalseam methane (CBM/CSM), basin-centered gas, shale gas, gas hydrates, natural bitumen and oil shale deposits. These unconventional accumulations may require specialized extraction technology and/or significant processing prior to sale.

Reserves do not include quantities of petroleum being held in inventory.

Because of the differences in uncertainty, caution should be exercised when aggregating quantities of petroleum from different reserves categories.

RESERVES (SEC DEFINITIONS)

Securities and Exchange Commission Regulation S-X §210.4-10(a)(26) defines reserves as follows:

Reserves. Reserves are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and gas or related substances to market, and all permits and financing required to implement the project.

Note to paragraph (a)(26): Reserves should not be assigned to adjacent reservoirs isolated by major, potentially sealing, faults until those reservoirs are penetrated and evaluated as economically producible. Reserves should not be assigned to areas that are clearly separated from a known accumulation by a non-productive reservoir (i.e., absence of reservoir, structurally low reservoir, or negative test results). Such areas may contain prospective resources (i.e., potentially recoverable resources from undiscovered accumulations).

PROVED RESERVES (SEC DEFINITIONS)

Securities and Exchange Commission Regulation S-X §210.4-10(a)(22) defines proved oil and gas reserves as follows:

Proved oil and gas reserves. Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.

(i) The area of the reservoir considered as proved includes:

(A) The area identified by drilling and limited by fluid contacts, if any, and

(B) Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

PETROLEUM RESERVES DEFINITIONS

Page 3

PROVED RESERVES (SEC DEFINITIONS) CONTINUED

(ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty.

(iii) Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty.

(iv) Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when:

(A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and

(B) The project has been approved for development by all necessary parties and entities, including governmental entities.

(v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

PETROLEUM RESERVES STATUS DEFINITIONS AND GUIDELINES

As Adapted From:

RULE 4-10(a) of REGULATION S-X PART 210

UNITED STATES SECURITIES AND EXCHANGE COMMISSION (SEC)

and

PETROLEUM RESOURCES MANAGEMENT SYSTEM (SPE-PRMS)

Sponsored and Approved by:

SOCIETY OF PETROLEUM ENGINEERS (SPE)

WORLD PETROLEUM COUNCIL (WPC)

AMERICAN ASSOCIATION OF PETROLEUM GEOLOGISTS (AAPG)

SOCIETY OF PETROLEUM EVALUATION ENGINEERS (SPEE)

Reserves status categories define the development and producing status of wells and reservoirs. Reference should be made to Title 17, Code of Federal Regulations, Regulation S-X Part 210, Rule 4-10(a) and the SPE-PRMS as the following reserves status definitions are based on excerpts from the original documents (direct passages excerpted from the aforementioned SEC and SPE-PRMS documents are denoted in italics herein).

DEVELOPED RESERVES (SEC DEFINITIONS)

Securities and Exchange Commission Regulation S-X §210.4-10(a)(6) defines developed oil and gas reserves as follows:

Developed oil and gas reserves are reserves of any category that can be expected to be recovered:

(i) Through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and

(ii) Through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well.

Developed Producing (SPE-PRMS Definitions)

While not a requirement for disclosure under the SEC regulations, developed oil and gas reserves may be further sub-classified according to the guidance contained in the SPE-PRMS as Producing or Non-Producing.

Developed Producing Reserves

Developed Producing Reserves are expected to be recovered from completion intervals that are open and producing at the time of the estimate.

Improved recovery reserves are considered producing only after the improved recovery project is in operation.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

PETROLEUM RESERVES STATUS DEFINITIONS AND GUIDELINES

Page 2

Developed Non-Producing

Developed Non-Producing Reserves include shut-in and behind-pipe reserves.

Shut-In

Shut-in Reserves are expected to be recovered from:

(1) completion intervals which are open at the time of the estimate, but which have not started producing;

(2) wells which were shut-in for market conditions or pipeline connections; or

(3) wells not capable of production for mechanical reasons.

Behind-Pipe

Behind-pipe Reserves are expected to be recovered from zones in existing wells, which will require additional completion work or future re-completion prior to start of production.

In all cases, production can be initiated or restored with relatively low expenditure compared to the cost of drilling a new well.

UNDEVELOPED RESERVES (SEC DEFINITIONS)

Securities and Exchange Commission Regulation S-X §210.4-10(a)(31) defines undeveloped oil and gas reserves as follows:

Undeveloped oil and gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion.

(i) Reserves on undrilled acreage shall be limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances.

(ii) Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances, justify a longer time.

(iii) Under no circumstances shall estimates for undeveloped reserves be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, as defined in paragraph (a)(2) of this section, or by other evidence using reliable technology establishing reasonable certainty.

RYDER SCOTT COMPANY     PETROLEUM CONSULTANTS

EX-10.3

Exhibit 10.3

(Part 1 of 3)

PRESIDENT - ROBERT C. BARG   VICE PRESIDENTS ALLEN E. EVANS, JR. RANDOLPH K.GREEN JOHN G. HATTNER C. H. (SCOTT) REES III DANNY D. SIMMONS DAN PAUL SMITH ERIC J. STEVENS

April 26, 2018

Ing. Carlos Alberto Treviño Medina

Petróleos Mexicanos

Avenida Marina Nacional 329

Torre Ejecutiva, Piso 44

Colonia Verónica Anzures

11300 Ciudad de México, México

Dear Ing. Treviño Medina:

We hereby consent to all references to our firm as set forth in the Annual Report on Form 20-F of Petróleos Mexicanos (“Pemex”) for the year ending December 31, 2017 (the “Form 20-F”), under the heading “Exploration and Production (Reserves),” and to the filing of our audit letter dated April 24, 2018, as an exhibit to the Form 20-F. We have audited the estimates of Pemex’s proved oil, condensate, natural gas, and oil equivalent reserves, as of January 1, 2018, for 71 fields located in the Poza Rica-Altamira District in the North Region of Mexico. These estimates were prepared by Pemex Exploración y Producción in accordance with the reserves definitions of Regulation S-X Rule 4-10(a) of the U.S. Securities and Exchange Commission.

Sincerely,
NETHERLAND, SEWELL INTERNATIONAL, S. DE R.L. DE C.V.
By:
	Robert C. Barg, P.E.
	President

RCB:LMS

2100 ROSS AVENUE, SUITE 2200 • DALLAS, TEXAS 75201-2737 • PH: 214-969-5401 • FAX: 214-969-5411

Exhibit 10.3

(Part 2 of 3)

PRESIDENT - ROBERT C. BARG   VICE PRESIDENTS ALLEN E. EVANS, JR. RANDOLPH K.GREEN JOHN G. HATTNER C. H. (SCOTT) REES III DANNY D. SIMMONS DAN PAUL SMITH ERIC J. STEVENS

April 26, 2018

Ing. Carlos Alberto Treviño Medina

Petróleos Mexicanos

Avenida Marina Nacional 329

Torre Ejecutiva, Piso 44

Colonia Verónica Anzures

11300 Ciudad de México, México

Dear Ing. Treviño Medina:

We hereby consent to all references to our firm as set forth in the Annual Report on Form 20-F of Petróleos Mexicanos (“Pemex”) for the year ending December 31, 2017 (the “Form 20-F”), under the heading “Exploration and Production (Reserves),” and to the filing of our audit letter dated April 24, 2018, as an exhibit to the Form 20-F. We have audited the estimates of Pemex’s proved oil, condensate, natural gas, and oil equivalent reserves, as of January 1, 2018, for 30 fields located in the Litoral de Tabasco Asset in the Southwest Marine Region. These estimates were prepared by Pemex Exploración y Producción in accordance with the reserves definitions of Regulation S-X Rule 4-10(a) of the U.S. Securities and Exchange Commission.

Sincerely,
NETHERLAND, SEWELL INTERNATIONAL, S. DE R.L. DE C.V.
By:
	Robert C. Barg, P.E.
	President

RCB:LMS

2100 ROSS AVENUE, SUITE 2200 • DALLAS, TEXAS 75201-2737 • PH: 214-969-5401 • FAX: 214-969-5411

Exhibit 10.3

(Part 3 of 3)

PRESIDENT - ROBERT C. BARG   VICE PRESIDENTS ALLEN E. EVANS, JR. RANDOLPH K.GREEN JOHN G. HATTNER C. H. (SCOTT) REES III DANNY D. SIMMONS DAN PAUL SMITH ERIC J. STEVENS

April 26, 2018

lng. Carlos Alberto Treviño Medina

Petróleos Mexicanos

Avenida Marina Nacional 329

Torre Ejecutiva, Piso 44

Colonia Verónica Anzures

11300 Ciudad de México, México

Dear lng. Treviño Medina:

We hereby consent to all references to our firm as set forth in the Annual Report on Form 20-F of Petróleos Mexicanos (“Pemex”) for the year ending December 31, 2017 (the “Form 20-F”), under the heading “Exploration and Production (Reserves),” and to the filing of our audit letter dated April 24, 2018, as an exhibit to the Form 20-F. We have audited the estimates of Pemex’s proved oil, condensate, natural gas, and oil equivalent reserves, as of January 1, 2018, for 27 fields located in the Aceite Terciario del Golfo District in Veracruz, Mexico. These estimates were prepared by Pemex Exploración y Producción in accordance with the reserves definitions of Regulation S-X Rule 4-10(a) of the U.S. Securities and Exchange Commission.

Sincerely,
NETHERLAND, SEWELL INTERNATIONAL, S. DE R.L. DE C.V.
By:
	Robert C. Barg, P.E.
	President

RCB:LMS

2100 ROSS AVENUE, SUITE 2200 • DALLAS, TEXAS 75201-2737 • PH: 214-969-5401 • FAX: 214-969-5411

EX-10.4

Exhibit 10.4

(Part 1 of 3)

April 24, 2018

Ing. J. Javier Hinojosa Puebla

Director General

Pemex Exploración y Producción

Avenida Marina Nacional 329

Torre Ejecutiva, Piso 41

Col. Verónica Anzures, C.P. 11300

Del. Miguel Hidalgo, Ciudad de México

México

Dear Ing. Hinojosa:

In accordance with your request, we have audited the estimates prepared by Pemex Exploración y Producción (PEP), as of January 1, 2018, of the gross (100 percent) proved reserves in portions of 71 fields located in the Poza Rica-Altamira District, Mexico. PEP is a subsidiary entity of Petróleos Mexicanos. The scope of our work did not include auditing the future net revenue associated with these reserves. The Political Constitution of the United Mexican States provides that the Mexican nation owns all petroleum and other hydrocarbon reserves for these fields; however, these fields have been assigned to and are currently operated by PEP. In accordance with the Energy Reform of 2014, the estimates in this report represent the gross (100 percent) proved reserves to be produced within the economic life of the properties. We have examined the estimates with respect to reserves quantities, reserves categorization, future producing rates, and economic producibility, using the definitions set forth in U.S. Securities and Exchange Commission (SEC) Regulation S-X Rule 4-10(a). Economic analysis was performed by PEP only to confirm economic producibility and determine economic limits for the properties. Without considering the inclusion of proved undeveloped locations drilled beyond 5 years of their original booking date, the estimates of reserves have been prepared in accordance with the definitions and regulations of the SEC and conform to the FASB Accounting Standards Codification Topic 932, Extractive Activities—Oil and Gas. We completed our audit on February 13, 2018. This report has been prepared for PEP’s and Petróleos Mexicanos’ use internally and in filings with the appropriate regulatory agencies. In our opinion the assumptions, data, methods, and procedures used in the preparation of this report are appropriate for such purpose; there is no guarantee or warranty, implied or expressed, by Netherland, Sewell International, S. de R.L. de C.V. (NSI) for any other use of this report.

The following table sets forth PEP’s estimates of the gross (100 percent) reserves, as of January 1, 2018, for the audited Poza Rica-Altamira District properties:

	Gross (100%) Reserves
Category	Oil(1) (MMBBL)		Condensate(2) (MMBBL)		Plant Liquids (MMBBL)		Dry Gas(3) (MMBOE)		BOE (MMBBL)
Proved Developed Producing		104.6		0.0		3.5		13.2		121.2
Proved Developed Non-Producing		31.6		0.0		1.4		5.4		38.4
Proved Undeveloped		91.0		0.0		3.2		9.6		103.9
Total Proved		227.2		0.0		8.1		28.2		263.5

⁽¹⁾ Oil reserves include oil plus liquids from the produced gas stream separated in the field.

⁽²⁾  Condensate reserves are the liquids volumes recovered from the produced gas stream during the compression and dehydration stages of processing.

⁽³⁾  Dry gas reserves are the dry, sweetened gas available for sale by Pemex Transformación Industrial at the tailgate of the processing plants.

2100 ROSS AVENUE, SUITE 2200 • DALLAS, TEXAS 75201-2737 • PH: 214-969-5401 • FAX: 214-969-5411

Oil, condensate, plant liquids, and barrels of oil equivalent (BOE) volumes are expressed in millions of barrels (MMBBL); a barrel is equivalent to 42 United States gallons. Dry gas volumes are expressed in millions of barrels of oil equivalent (MMBOE), determined using dry gas conversion factors provided by PEP.

When compared on a field-by-field basis, some of the estimates of PEP are greater and some are less than the estimates of NSI. However, in our opinion the estimates of reserves prepared by PEP shown herein are reasonable when aggregated at the total proved level and have been prepared in accordance with the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers (SPE Standards). Additionally, these estimates are within the recommended 10 percent tolerance threshold set forth in the SPE Standards and adhere to the SEC definitions, except that it is our understanding that a significant portion of the proved undeveloped reserves are associated with locations that have been categorized as proved undeveloped for longer than 5 years. We are satisfied with the methods and procedures used by PEP in preparing the January 1, 2018, estimates of reserves, and we saw nothing of an unusual nature that would cause us to take exception with the estimates, in the aggregate, as prepared by PEP.    

Reserves categorization conveys the relative degree of certainty; reserves subcategorization is based on development and production status. The estimates of reserves included herein have not been adjusted for risk. PEP’s estimates do not include probable or possible reserves that exist for these properties.    

Oil and gas prices were used only to confirm economic producibility and determine economic limits for the properties. It is our understanding that prices used by PEP are representative of the 12-month average for the period January through December 2017. NSI accepted the prices provided without independent review or verification. All prices are held constant throughout the lives of the properties.

Costs were used only to confirm economic producibility and determine economic limits for the properties. It is our understanding that operating costs used by PEP are representative of the 12-month average for the period January through December 2017. These costs include district and regional overhead expenses along with costs to be incurred at the field level. Operating costs for certain undeveloped fields are based on PEP’s analogy to a similar type of producing field. Operating costs have been divided into field-level costs, per-well costs, and per-unit-of-production costs. No headquarters general and administrative overhead expenses are included. Capital costs used by PEP are based on authorizations for expenditure and actual costs from recent activity. Capital costs are included as required for workovers, new development wells, and production equipment. Abandonment costs used are PEP’s estimates of the costs to abandon the wells, platforms, and production facilities, net of any salvage value. NSI accepted the operating cost parameters and the capital and abandonment costs provided without independent review or verification. Operating, capital, and abandonment costs are not escalated for inflation.

The reserves shown in this report are estimates only and should not be construed as exact quantities. Proved reserves are those quantities of oil and gas which, by analysis of engineering and geoscience data, can be estimated with reasonable certainty to be economically producible; probable and possible reserves are those additional reserves which are sequentially less certain to be recovered than proved reserves. Estimates of reserves may increase or decrease as a result of market conditions, future operations, changes in regulations, or actual reservoir performance. In addition to the primary economic assumptions discussed herein, estimates of PEP and NSI are based on certain assumptions including, but not limited to, that the properties will be developed consistent with current development plans as provided to us by PEP, that the properties will be operated in a prudent manner, that no governmental regulations or controls will be put in place that would impact the ability of PEP to produce and recover the reserves, and that projections of future production will prove consistent with actual performance. If the reserves are recovered, the revenues therefrom and the costs related thereto could be more or less than the estimated amounts used to confirm economic producibility and determine economic limits for the properties. Because of governmental policies and uncertainties of supply and demand, the sales rates, prices received for the reserves, and costs incurred in recovering such reserves may vary from assumptions made while preparing these estimates.

It should be understood that our audit does not constitute a complete reserves study of the audited oil and gas properties. Our audit consisted primarily of substantive testing, wherein we conducted a detailed review of all properties making up the total proved reserves. In the conduct of our audit, we have not independently verified the accuracy and completeness of information and data furnished by PEP with respect to oil and gas production, well test data, historical costs of operation and development, product prices, or any agreements relating to current and future operations of the properties and sales of production. Our audit did not include a review of PEP’s overall reserves management processes and practices.

We used standard engineering and geoscience methods, or a combination of methods, including performance analysis, volumetric analysis, and analogy, that we considered to be appropriate and necessary to establish the conclusions set forth herein. As in all aspects of oil and gas evaluation, there are uncertainties inherent in the interpretation of engineering and geoscience data; therefore, our conclusions necessarily represent only informed professional judgment.

Supporting data documenting this audit, along with data provided by PEP, are on file in our office. The technical persons primarily responsible for conducting this audit meet the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the SPE Standards. Eric J. Stevens, a Licensed Professional Engineer in the State of Texas, has been practicing consulting petroleum engineering at Netherland, Sewell & Associates, Inc. (NSAI), of which NSI is a subsidiary, since 2007 and has 5 years of prior industry experience. Michelle F. Herrera, a Licensed Professional Geoscientist in the State of Texas, has been practicing consulting petroleum geoscience at NSAI since 2013 and has 10 years of prior industry experience. We are independent petroleum engineers, geologists, geophysicists, and petrophysicists; we do not own an interest in these properties nor are we employed on a contingent basis.

			Sincerely,
			NETHERLAND, SEWELL INTERNATIONAL, S. DE R.L. DE C.V.
			By:
				Robert C. Barg, P.E.
				President
By:			By:
	Eric J. Stevens, P.E. 102415 Vice President			Michelle F. Herrera, P.G. 11912 Geoscientist
Date Signed: April 24, 2018			Date Signed: April 24, 2018
EJS:DSS

Exhibit 10.4

(Part 2 of 3)

April 24, 2018

Ing. J. Javier Hinojosa Puebla

Director General

Pemex Exploración y Producción

Avenida Marina Nacional 329

Torre Ejecutiva, Piso 41

Col. Verónica Anzures, C.P. 11300

Del. Miguel Hidalgo, Ciudad de México

México

Dear Ing. Hinojosa:

In accordance with your request, we have audited the estimates prepared by Pemex Exploración y Producción (PEP), as of January 1, 2018, of the gross (100 percent) proved reserves in 30 fields located in the Litoral de Tabasco District, Mexico. PEP is a subsidiary entity of Petróleos Mexicanos. The scope of our work did not include auditing the future net revenue associated with these reserves. The Political Constitution of the United Mexican States provides that the Mexican nation owns all petroleum and other hydrocarbon reserves for these fields; however, these fields have been assigned to and are currently operated by PEP. In accordance with the Energy Reform of 2014, the estimates in this report represent the gross (100 percent) proved reserves to be produced within the economic life of the properties. We have examined the estimates with respect to reserves quantities, reserves categorization, future producing rates, and economic producibility, using the definitions set forth in U.S. Securities and Exchange Commission (SEC) Regulation S-X Rule 4-10(a). Economic analysis was performed by PEP only to confirm economic producibility and determine economic limits for the properties. The estimates of reserves have been prepared in accordance with the definitions and regulations of the SEC and conform to the FASB Accounting Standards Codification Topic 932, Extractive Activities—Oil and Gas. We completed our audit on February 13, 2018. This report has been prepared for PEP’s and Petróleos Mexicanos’ use internally and in filings with the appropriate regulatory agencies. In our opinion the assumptions, data, methods, and procedures used in the preparation of this report are appropriate for such purpose; there is no guarantee or warranty, implied or expressed, by Netherland, Sewell International, S. de R.L. de C.V. (NSI) for any other use of this report.

The following table sets forth PEP’s estimates of the gross (100 percent) reserves, as of January 1, 2018, for the audited Litoral de Tabasco District properties:

	Gross (100%) Reserves
	Oil(1)		Condensate(2)		Plant Liquids		Dry Gas(3)		BOE
Category	(MMBBL)		(MMBBL)		(MMBBL)		(MMBOE)		(MMBBL)
Proved Developed Producing		205.4		7.9		50.4		79.2		343.0
Proved Developed Non-Producing		4.2		0.0		0.1		0.1		4.4
Proved Undeveloped		346.5		5.4		24.5		100.7		477.1
Total Proved		556.1		13.3		75.0		180.0		824.5

⁽¹⁾  Oil reserves include oil plus liquids from the produced gas stream separated in the field.

⁽²⁾  Condensate reserves are the liquids volumes recovered from the produced gas stream during the compression and dehydration stages of processing.

⁽³⁾  Dry gas reserves are the dry, sweetened gas available for sale by Pemex Transformación Industrial at the tailgate of the processing plants.

2100 ROSS AVENUE SUITE 2200 - DALLAS, TEXAS 75201-2737 •. PH: 214-969-5401 • FAX: 214-969-5411

Oil, condensate, plant liquids, and barrels of oil equivalent (BOE) volumes are expressed in millions of barrels (MMBBL); a barrel is equivalent to 42 United States gallons. Dry gas volumes are expressed in millions of barrels of oil equivalent (MMBOE), determined using dry gas conversion factors provided by PEP.

When compared on a field-by-field basis, some of the estimates of PEP are greater and some are less than the estimates of NSI. However, in our opinion the estimates of reserves prepared by PEP shown herein are reasonable when aggregated at the total proved level and have been prepared in accordance with the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers (SPE Standards). Additionally, these estimates are within the recommended 10 percent tolerance threshold set forth in the SPE Standards. We are satisfied with the methods and procedures used by PEP in preparing the January 1, 2018, estimates of reserves, and we saw nothing of an unusual nature that would cause us to take exception with the estimates, in the aggregate, as prepared by PEP.

Reserves categorization conveys the relative degree of certainty; reserves subcategorization is based on development and production status. The estimates of reserves included herein have not been adjusted for risk. PEP’s estimates do not include probable or possible reserves that exist for these properties.    

Oil and gas prices were used only to confirm economic producibility and determine economic limits for the properties. It is our understanding that prices used by PEP are representative of the 12-month average for the period January through December 2017. NSI accepted the prices provided without independent review or verification. All prices are held constant throughout the lives of the properties.

Costs were used only to confirm economic producibility and determine economic limits for the properties. It is our understanding that operating costs used by PEP are representative of the 12-month average for the period January through December 2017. These costs include district and regional overhead expenses along with costs to be incurred at the field level. Operating costs for certain undeveloped fields are based on PEP’s analogy to a similar type of producing field. Operating costs have been divided into field-level costs, per-well costs, and per-unit-of-production costs. No headquarters general and administrative overhead expenses are included. Capital costs used by PEP are based on authorizations for expenditure and actual costs from recent activity. Capital costs are included as required for workovers, new development wells, and production equipment. Abandonment costs used are PEP’s estimates of the costs to abandon the wells, platforms, and production facilities, net of any salvage value. NSI accepted the operating cost parameters and the capital and abandonment costs provided without independent review or verification. Operating, capital, and abandonment costs are not escalated for inflation.

The reserves shown in this report are estimates only and should not be construed as exact quantities. Proved reserves are those quantities of oil and gas which, by analysis of engineering and geoscience data, can be estimated with reasonable certainty to be economically producible; probable and possible reserves are those additional reserves which are sequentially less certain to be recovered than proved reserves. Estimates of reserves may increase or decrease as a result of market conditions, future operations, changes in regulations, or actual reservoir performance. In addition to the primary economic assumptions discussed herein, estimates of PEP and NSI are based on certain assumptions including, but not limited to, that the properties will be developed consistent with current development plans as provided to us by PEP, that the properties will be operated in a prudent manner, that no governmental regulations or controls will be put in place that would impact the ability of PEP to produce and recover the reserves, and that projections of future production will prove consistent with actual performance. If the reserves are recovered, the revenues therefrom and the costs related thereto could be more or less than the estimated amounts used to confirm economic producibility and determine economic limits for the properties. Because of governmental policies and uncertainties of supply and demand, the sales rates, prices received for the reserves, and costs incurred in recovering such reserves may vary from assumptions made while preparing these estimates.

It should be understood that our audit does not constitute a complete reserves study of the audited oil and gas properties. Our audit consisted primarily of substantive testing, wherein we conducted a detailed review of all properties making up the total proved reserves. In the conduct of our audit, we have not independently verified the

accuracy and completeness of information and data furnished by PEP with respect to oil and gas production, well test data, historical costs of operation and development, product prices, or any agreements relating to current and future operations of the properties and sales of production. Our audit did not include a review of PEP’s overall reserves management processes and practices.

We used standard engineering and geoscience methods, or a combination of methods, including performance analysis, volumetric analysis, analogy, and reservoir modeling, that we considered to be appropriate and necessary to establish the conclusions set forth herein. As in all aspects of oil and gas evaluation, there are uncertainties inherent in the interpretation of engineering and geoscience data; therefore, our conclusions necessarily represent only informed professional judgment.

Supporting data documenting this audit, along with data provided by PEP, are on file in our office. The technical persons primarily responsible for conducting this audit meet the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the SPE Standards. Andres F. Castaño, a Licensed Professional Engineer in the State of Texas, has been practicing consulting petroleum engineering at Netherland, Sewell & Associates, Inc. (NSAI), of which NSI is a subsidiary, since 2013 and has 8 years of prior industry experience. Allen E. Evans, Jr., a Licensed Professional Geoscientist in the State of Texas, has been practicing consulting petroleum geoscience at NSAI since 1996 and has 13 years of prior industry experience. We are independent petroleum engineers, geologists, geophysicists, and petrophysicists; we do not own an interest in these properties nor are we employed on a contingent basis.

			Sincerely,
			NETHERLAND, SEWELL INTERNATIONAL, S. DE R.L. DE C.V.
			By:
				Robert C. Barg, P.E.
				President
By:			By:
	Andres F. Castaño, P.E. 121698 Petroleum Engineer			Allen E. Evans, Jr., P.G. 1286 Vice President
Date Signed: April 24, 2018			Date Signed: April 24, 2018
AFC:LMS

Exhibit 10.4

(Part 3 of 3)

April 24, 2018

Ing. J. Javier Hinojosa Puebla

Director General

Pemex Exploración y Producción

Avenida Marina Nacional 329

Torre Ejecutiva, Piso 41

Col. Verónica Anzures, C.P. 11300

Del. Miguel Hidalgo, Ciudad de México

México

Dear Ing. Hinojosa:

In accordance with your request, we have audited the estimates prepared by Pemex Exploración y Producción (PEP), as of January 1, 2018, of the gross (100 percent) proved reserves in portions of 27 fields located in the Aceite Terciario del Golfo District, Veracruz, Mexico. PEP is a subsidiary entity of Petróleos Mexicanos. The scope of our work did not include auditing the future net revenue associated with these reserves. The Political Constitution of the United Mexican States provides that the Mexican nation owns all petroleum and other hydrocarbon reserves for these fields; however, these fields have been assigned to and are currently operated by PEP. In accordance with the Energy Reform of 2014, the estimates in this report represent the gross (100 percent) proved reserves to be produced within the economic life of the properties. We have examined the estimates with respect to reserves quantities, reserves categorization, future producing rates, and economic producibility, using the definitions set forth in U.S. Securities and Exchange Commission (SEC) Regulation S-X Rule 4-10(a). Economic analysis was performed by PEP only to confirm economic producibility and determine economic limits for the properties. Without considering (1) the accelerated development pace and (2) the inclusion of proved undeveloped locations drilled beyond 5 years of their original booking date, the estimates of reserves have been prepared in accordance with the definitions and regulations of the SEC and conform to the FASB Accounting Standards Codification Topic 932, Extractive Activities—Oil and Gas. These considerations are discussed in a subsequent paragraph of this letter. We completed our audit on February 13, 2018. This report has been prepared for PEP’s and Petróleos Mexicanos’ use internally and in filings with the appropriate regulatory agencies. In our opinion the assumptions, data, methods, and procedures used in the preparation of this report are appropriate for such purpose; there is no guarantee or warranty, implied or expressed, by Netherland, Sewell International, S. de R.L. de C.V. (NSI) for any other use of this report.

The following table sets forth PEP’s estimates of the gross (100 percent) reserves, as of January 1, 2018, for the audited Aceite Terciario del Golfo District properties:

	Gross (100%) Reserves
	Oil(1)		Condensate(2)		Plant Liquids		Dry Gas(3)		BOE
Category	(MMBBL)		(MMBBL)		(MMBBL)		(MMBOE)		(MMBBL)
Proved Developed Producing		20.3		0.0		3.3		7.9		31.5
Proved Developed Non-Producing		70.8		0.0		6.8		16.4		94.1
Proved Undeveloped		350.7		0.0		41.9		102.0		494.6
Total Proved		441.8		0.0		52.0		126.4		620.1

⁽¹⁾  Oil reserves include oil plus liquids from the produced gas stream separated in the field.

⁽²⁾  Condensate reserves are the liquids volumes recovered from the produced gas stream during the compression and dehydration stages of processing.

⁽³⁾  Dry gas reserves are the dry, sweetened gas available for sale by Pemex Transformación Industrial at the tailgate of the processing plants.

2100 ROSS AVENUE, SUITE 2200 • DALLAS, TEXAS 75201-2737 • PH: 214-969-5401 • FAX: 214-963-5411

Oil, condensate, plant liquids, and barrels of oil equivalent (BOE) volumes are expressed in millions of barrels (MMBBL); a barrel is equivalent to 42 United States gallons. Dry gas volumes are expressed in millions of barrels of oil equivalent (MMBOE), determined using dry gas conversion factors provided by PEP.

In our opinion, the estimates of proved reserves shown herein have been prepared in accordance with generally accepted petroleum engineering and evaluation principles set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers (SPE Standards) and, aside from the following considerations, adhere to the SEC definitions. First, the development plan incorporated in these estimates represents a more accelerated drilling pace than the recent development drilling. Focused development of the Chicontepec formation began in 2007, and to date, over 4,500 wells have been drilled. Development drilling peaked in 2009 with the drilling of 794 wells; however, in recent years development has slowed, with approximately 100 wells drilled from 2015 through 2017. Based on discussions with PEP, its development plan consists of drilling more than 33,000 wells over the next 35 years to develop the Chicontepec formation. PEP has indicated a commitment to develop the Aceite Terciario del Golfo District and plans to drill 33 proved undeveloped locations in 2018, ramping up to a maximum of 999 proved undeveloped locations in 2021. The time period for development of proved reserves locations is restricted to 5 years. Second, it is our understanding that a significant portion of the proved undeveloped reserves are associated with locations that have been categorized as proved undeveloped for longer than 5 years.

When compared on a field-by-field basis, some of the estimates of PEP are greater and some are less than the estimates of NSI. However, in our opinion the estimates of reserves prepared by PEP shown herein are reasonable when aggregated at the total proved level and have been prepared in accordance with the SPE Standards. Additionally, these estimates are within the recommended 10 percent tolerance threshold set forth in the SPE Standards. We are satisfied with the methods and procedures used by PEP in preparing the January 1, 2018, estimates of reserves, and we saw nothing of an unusual nature that would cause us to take exception with the estimates, in the aggregate, as prepared by PEP.

Reserves categorization conveys the relative degree of certainty; reserves subcategorization is based on development and production status. The estimates of reserves included herein have not been adjusted for risk. PEP’s estimates do not include probable or possible reserves that exist for these properties.

Oil and gas prices were used only to confirm economic producibility and determine economic limits for the properties. It is our understanding that prices used by PEP are representative of the 12-month average for the period January through December 2017. NSI accepted the prices provided without independent review or verification. All prices are held constant throughout the lives of the properties.

Costs were used only to confirm economic producibility and determine economic limits for the properties. It is our understanding that operating costs used by PEP are representative of the 12-month average for the period January through December 2017. These costs include district and regional overhead expenses along with costs to be incurred at the field level. Operating costs for certain undeveloped fields are based on PEP’s analogy to a similar type of producing field. Operating costs have been divided into field-level costs, per-well costs, and per-unit-of-production costs. No headquarters general and administrative overhead expenses are included. Capital costs used by PEP are based on authorizations for expenditure and actual costs from recent activity. Capital costs are included as required for workovers, new development wells, and production equipment. Abandonment costs used are PEP’s estimates of the costs to abandon the wells and production facilities, net of any salvage value. NSI accepted the operating cost parameters and the capital and abandonment costs provided without independent review or verification. Operating, capital, and abandonment costs are not escalated for inflation.

The reserves shown in this report are estimates only and should not be construed as exact quantities. Proved reserves are those quantities of oil and gas which, by analysis of engineering and geoscience data, can be estimated with reasonable certainty to be economically producible; probable and possible reserves are those additional reserves which are sequentially less certain to be recovered than proved reserves. Estimates of reserves may increase or decrease as a result of market conditions, future operations, changes in regulations, or actual reservoir performance. In addition to the primary economic assumptions discussed herein, estimates of PEP and NSI are based on certain assumptions including, but not limited to, that the properties will be developed consistent with current development plans as provided to us by PEP, that the properties will be operated in a prudent manner, that no governmental regulations or controls will be put in place that would impact the ability of PEP to produce and recover the reserves, and that projections of future production will prove consistent with actual performance. A

portion of these reserves are for properties operated by service contractors that are involved with the investment, planning, and development in accordance with their agreements with PEP. The development plan incorporated in this report was provided by PEP; this development plan may differ from development plans of individual service contract operators. If the reserves are recovered, the revenues therefrom and the costs related thereto could be more or less than the estimated amounts used to confirm economic producibility and determine economic limits for the properties. Because of governmental policies and uncertainties of supply and demand, the sales rates, prices received for the reserves, and costs incurred in recovering such reserves may vary from assumptions made while preparing these estimates.

It should be understood that our audit does not constitute a complete reserves study of the audited oil and gas properties. Our audit consisted primarily of substantive testing, wherein we conducted a detailed review of all properties making up the total proved reserves. In the conduct of our audit, we have not independently verified the accuracy and completeness of information and data furnished by PEP with respect to oil and gas production, well test data, historical costs of operation and development, product prices, or any agreements relating to current and future operations of the properties and sales of production. Our audit did not include a review of PEP’s overall reserves management processes and practices.

We used standard engineering and geoscience methods, or a combination of methods, including performance analysis and analogy, that we considered to be appropriate and necessary to establish the conclusions set forth herein. As in all aspects of oil and gas evaluation, there are uncertainties inherent in the interpretation of engineering and geoscience data; therefore, our conclusions necessarily represent only informed professional judgment.

Supporting data documenting this audit, along with data provided by PEP, are on file in our office. The technical persons primarily responsible for conducting this audit meet the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the SPE Standards. Eric J. Stevens, a Licensed Professional Engineer in the State of Texas, has been practicing consulting petroleum engineering at Netherland, Sewell & Associates, Inc. (NSAI), of which NSI is a subsidiary, since 2007 and has 5 years of prior industry experience. Dana D. Coryell, a Licensed Professional Geoscientist in the State of Texas, has been practicing consulting petroleum geoscience at NSAI since 1999 and has 15 years of prior industry experience. We are independent petroleum engineers, geologists, geophysicists, and petrophysicists; we do not own an interest in these properties nor are we employed on a contingent basis.

			Sincerely,
			NETHERLAND, SEWELL INTERNATIONAL, S. DE R.L. DE C.V.
			By:
				Robert C. Barg, P.E.
				President
By:			By:
	Eric J. Stevens, P.E. 102415 Petroleum Engineer			Dana D. Coryell, P.G. 10566 Geoscientist
Date Signed: April 24, 2018			Date Signed: April 24, 2018
JMW:ARC

EX-10.5

Exhibit 10.5

(Part 1 of 2)

DEGOLYER AND MACNAUGHTON

5001 SPRING VALLEY ROAD

SUITE 800 EAST

DALLAS, TEXAS 75244

April 26, 2018

Ing. Carlos Alberto Treviño Medina

Director General

Petróleos Mexicanos

Avenida Marina Nacional No. 329

Torre Ejecutiva, Piso 44

Colonia Verónica Anzures

11300 Ciudad de México, México

Dear Ing. Treviño Medina:

We hereby consent to the references to DeGolyer and MacNaughton as set forth under the headings “Presentation of Information Concerning Reserves,” “Item 4. Information on the Company – Business Overview – Exploration and Production – Reserves,” and “Item 19. Exhibits. Documents filed as exhibits to this Form 20-F” in the Annual Report on Form 20-F of Petróleos Mexicanos (PEMEX) for the year ended December 31, 2017 (the Form 20-F), and to the filing as Exhibit 10.6 to the Form 20-F of our report of third party dated April 20, 2018, describing our independent reserves evaluation of the estimated proved oil, marketable gas, sales gas, condensate, natural gas liquids (NGL), and oil equivalent reserves that PEMEX has represented are owned by the United Mexican States (México) as of January 1, 2018, for certain fields located in the Burgos area of México, which include reserves that PEMEX has represented that it has the right to extract and sell. These estimates were prepared ‘in accordance with the reseres definitions of Rules 4-10(a) (1)-(32) of Regulation s-x of the United States Securities and Exchange Commission.

Very truly yours,

DeGOLYER and MacNAUGHTON

Texas Registered Engineering Firm F-716

Exhibit 10.5

(Part 2 of 2)

DEGOLYER AND MACNAUGHTON

5001 SPRING VALLEY ROAD

SUITE 800 EAST

DALLAS, TEXAS 75244

April 26, 2018

Ing. Carlos Alberto Treviño Medina

Director General

Petróleos Mexicanos

Avenida Marina Nacional No. 329

Torre Ejecutiva, Piso 44

Colonia Verónica Anzures

11300 Ciudad de México, México

Dear Ing. Treviño Medina:

We hereby consent to the references to DeGolyer and MacNaughton as set forth under the headings “Presentation of Information Concerning Reserves,” “Item 4. Information on the Company – Business Overview – Exploration and Production – Reserves,” and “Item 19. Exhibits. Documents filed as exhibits to this Form 20-F” in the Annual Report on Form 20-F of Petróleos Mexicanos (PEMEX) for the year ended December 31, 2017 (the Form 20-F), and to the filing as Exhibit 10.6 to the Form 20-F of our report of third party dated April 20, 2018, describing our independent reserves evaluation of the estimated proved oil, marketable gas, sales gas, condensate, natural gas liquids (NGL), and oil equivalent reserves that PEMEX has represented are owned by the United Mexican States (México) as of January 1, 2018, for certain fields located in the Veracruz area of México, which include reserves that PEMEX has represented that it has the right to extract and sell. These estimates were prepared in accordance with the reserves definitions of Rules 4-10(a) (l)-(32) of Regulation S-X of the United States Securities and Exchange Commission.

Very truly yours,

DeGOLYER and MacNAUGHTON

Texas Registered Engineering Firm F-716

EX-10.6

Exhibit 10.6

(Part 1 of 2)

DEGOLYER AND MACNAUGHTON

5001 SPRING VALLEY ROAD

SUITE 800 EAST

DALLAS, TEXAS 75244

This is a digital representation of a DeGolyer and MacNaughton report.

This file is intended to be a manifestation of certain data in the subject report and as such are subject to the same conditions thereof. The information and data contained in this file may be subject to misinterpretation; therefore, the signed and bound copy of this report should be considered the only authoritative source of such information.

DEGOLYER AND MACNAUGHTON

5001 SPRING VALLEY ROAD

SUITE 800 EAST

DALLAS, TEXAS 75244

April 20, 2018

Ing. J. Javier Hinojosa Puebla

Director General de Pemex Exploración y Producción

Avenida Marina Nacional 329

Torre Ejecutiva, Piso 41

Col. Verónica Anzures, C.P. 11300

Del. Miguel Hidalgo, Ciudad de México

Dear Ing. Hinojosa,

Pursuant to your request, DeGolyer and MacNaughton has conducted an independent reserves evaluation of the net proved oil, gas, condensate, and oil equivalent reserves, as of January 1, 2018, of certain properties that PEMEX Exploración y Producción (PEP) has represented are owned by the United Mexican States in the Burgos area of Mexico. This evaluation was completed on February 15, 2018. PEP has represented that these properties account for 2.4 percent on a net oil equivalent barrel basis of the net proved reserves assigned to PEP, as of January 1, 2018, and that the net proved reserves estimates have been prepared in accordance with the reserves definitions of Rules 4–10(a) (1)–(32) of Regulation S–X of the Securities and Exchange Commission (SEC) of the United States. At the request of PEP, this report also includes estimates prepared by PEP of its natural gas liquids (NGL) reserves; however, PEP has represented that PEP’s management of the properties stops at the inlet of the gas processing plants. PEP has represented that all subsurface hydrocarbons belong to the United Mexican States, and has further represented that PEP has received a 100-percent assignment in these properties by the United Mexican States; therefore, gross reserves are equal to net reserves and are defined as the total estimated petroleum to be produced from these properties after December 31, 2017. We have reviewed information provided to us by PEP that it represents to be PEP’s estimates of the net proved reserves, as of January 1, 2018, for the same properties as those which we evaluated. This report was prepared in accordance with guidelines specified in Item 1202 (a)(8) of Regulation S-K and is to be used for inclusion in certain SEC filings by PEP.

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DEGOLYER AND MACNAUGHTON

Based on Mexico’s Energy Reform of 2014, PEP has represented that its estimates of the net proved reserves assigned to PEP presented in this report correspond to 99.8 percent of the total net proved reserves of the Burgos area assigned to PEP, on an oil equivalent basis.

Reserves estimates included herein are expressed as net reserves as represented by PEP. Gross reserves are defined as the total estimated petroleum to be produced from these properties after December 31, 2017. Net reserves are defined as that portion of the gross reserves attributable to the interests owned by the United Mexican States after deducting all interests owned by others.

Estimates of oil, gas, condensate, NGL, and oil equivalent reserves should be regarded only as estimates that may change as further production history and additional information become available. Not only are such reserves estimates based on that information which is currently available, but such estimates are also subject to the uncertainties inherent in the application of judgmental factors in interpreting such information.

Data used in this evaluation were obtained from reviews with PEP personnel, from PEP files, from records on file with the appropriate regulatory agencies, and from public sources. In the preparation of this report we have relied, without independent verification, upon such information furnished by PEP with respect to property interests, production from such properties, current costs of operation and development, current prices for production, agreements relating to current and future operations and sale of production, and various other information and data that were accepted as represented. A field examination of the properties was not considered necessary for the purposes of this report.

Methodology and Procedures

Estimates of reserves were prepared by the use of appropriate geologic, petroleum engineering, and evaluation principles and techniques that are in accordance with practices generally recognized by the petroleum industry as presented in the publication of the Society of Petroleum Engineers entitled “Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information (Revision as of February 19, 2007).” The method or combination of methods used in the analysis of each reservoir was tempered by experience with similar reservoirs, stage of development, quality and completeness of basic data, and production history.

3

DEGOLYER AND MACNAUGHTON

Based on the current stage of field development, production performance, the development plans provided by PEP, and analyses of areas offsetting existing wells with test or production data, reserves were classified as proved.

When applicable, the volumetric method was used to estimate the original oil in place (OOIP) and the original gas in place (OGIP). Structure and isopach maps were constructed to estimate reservoir volume. Electrical logs, radioactivity logs, core analyses, and other available data were used to prepare these maps as well as to estimate representative values for porosity and water saturation. When adequate data were available and when circumstances justified, material balance and other engineering methods were used to estimate OOIP or OGIP.

Estimates of ultimate recovery were obtained after applying recovery factors to OOIP or OGIP. These recovery factors were based on consideration of the type of energy inherent in the reservoirs, analyses of the petroleum, the structural positions of the properties, and the production histories. When applicable, material balance and other engineering methods were used to estimate recovery factors. In such cases, an analysis of reservoir performance, including production rate, reservoir pressure, and gas-oil ratio behavior, was used in the estimation of reserves.

For depletion-type reservoirs or those whose performance disclosed a reliable decline in producing-rate trends or other diagnostic characteristics, reserves were estimated by the application of appropriate decline curves or other performance relationships. In the analyses of production-decline curves, reserves were estimated only to the limits of economic production based on existing economic conditions.

Gas quantities estimated herein are expressed as marketable gas and sales gas at a temperature base of 20 degrees Celsius and at a pressure base of 1 atmosphere. Marketable gas is defined as the total gas in the reservoirs to be produced after shrinkage resulting from field separation and flare. Marketable gas includes fuel. Sales gas is defined as the total gas to be produced from the reservoirs, measured at the point of delivery, after reduction for injection, fuel usage, flare, and shrinkage resulting from field separation and plant processing. Oil, condensate, and NGL reserves estimated herein are expressed in terms of 42 United States gallons per barrel. Oil and condensate reserves estimated herein are to be recovered by normal field separation. PEP has represented that its NGL reserves have been estimated on the basis of the quantities of liquids recovered from gas delivered to a gas plant for processing, and can include propane, butane, and C5+ fractions.

4

DEGOLYER AND MACNAUGHTON

Definition of Reserves

Petroleum reserves estimated by PEP included in this report are classified as proved. Only proved reserves have been evaluated for this report. Reserves classifications used by PEP in this report are in accordance with the reserves definitions of Rules 4–10(a) (1)–(32) of Regulation S–X of the SEC. Reserves are judged to be economically producible in future years from known reservoirs under existing economic and operating conditions and assuming continuation of current regulatory practices using conventional production methods and equipment. In the analyses of production-decline curves, reserves were estimated only to the limit of economic rates of production under existing economic and operating conditions using prices and costs consistent with the effective date of this report, including consideration of changes in existing prices provided only by contractual arrangements but not including escalations based upon future conditions. The petroleum reserves are classified as follows:

Proved oil and gas reserves – Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.

(i) The area of the reservoir considered as proved includes:

(A) The area identified by drilling and limited by fluid contacts, if any, and (B) Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.

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DEGOLYER AND MACNAUGHTON

(ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty.

(iii) Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty.

(iv) Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when:

(A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and (B) The project has been approved for development by all necessary parties and entities, including governmental entities.

(v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.

Developed oil and gas reserves – Developed oil and gas reserves are reserves of any category that can be expected to be recovered:

(i) Through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and

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DEGOLYER AND MACNAUGHTON

(ii) Through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well.

Undeveloped oil and gas reserves – Undeveloped oil and gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion.

(i) Reserves on undrilled acreage shall be limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances.

(ii) Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances justify a longer time.

(iii) Under no circumstances shall estimates for undeveloped reserves be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, as defined in [section 210.4–10 (a) Definitions], or by other evidence using reliable technology establishing reasonable certainty.

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DEGOLYER AND MACNAUGHTON

Primary Economic Assumptions

The following economic assumptions were used for estimating existing and future prices and costs, expressed in United States dollars (U.S.$):

Condensate Prices

PEP has represented that the condensate prices were based on a reference price, calculated as the unweighted arithmetic average of the first-day-of-the-month price for each month within the 12-month period prior to the end of the reporting period. As represented by PEP, the reference price utilized is the Mexican Mix reference price, which is composed of the Istmo, Maya, and Olmeca reference prices and is calculated based on a formula that includes the West Texas Sour, Light Louisiana Sweet, Brent, Oman, and Dubai reference prices. PEP supplied differentials by field to an average Mexican Mix reference price of U.S.$52.32 per barrel and the prices were held constant thereafter. The volume-weighted average adjusted price attributable to estimated proved reserves for the fields that were evaluated was U.S.$48.34 per barrel for condensate. These prices were not escalated for inflation.

Gas Prices

PEP has represented that the gas prices were based on a 12-month average price, calculated as the unweighted arithmetic average of the first-day-of-the-month price for each month within the 12-month period prior to the end of the reporting period, unless prices are defined by contractual arrangements. Each field’s calorific value, which includes NGL, was used to determine each field’s gas price. The volume-weighted average adjusted price for the fields that were evaluated was U.S.$3.79 per thousand cubic feet. These prices were not escalated for inflation.

Operating Expenses, Capital Costs, and Abandonment Costs

Operating expenses and capital costs, based on information provided by PEP, were used in estimating future costs required to operate the properties. In certain cases, future costs, either higher or lower than existing costs, may have been used because of anticipated changes in operating conditions. These costs were not escalated for inflation. Abandonment costs were provided by PEP.

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DEGOLYER AND MACNAUGHTON

While the oil and gas industry may be subject to regulatory changes from time to time that could affect an industry participant’s ability to recover its reserves, we are not aware of any such governmental actions which would restrict the recovery of the January 1, 2018, estimated reserves.

PEP has represented that its estimated net proved reserves attributable to the reviewed properties were based on the definition of proved reserves of the SEC. PEP has represented that its estimates of the net proved reserves attributable to these properties, which represent 2.4 percent of PEP’s reserves on a net oil equivalent basis, are summarized as follows, expressed in millions of barrels (MMbbl), billions of cubic feet (Bcf), and millions of barrels of oil equivalent (MMboe):

Estimated by PEP Net Proved Reserves as of January 1, 2018

Properties Reviewed by DeGolyer and MacNaughton

Oil (MMbbl)

Marketable Gas (Bcf)

Sales Gas (Bcf)

Condensate (MMbbl)

NGL (MMbbl)

Oil Equivalent (MMboe)

Burgos Area

Total Proved

0.00

971.81

818.52

14.18

15.10

182.22

Notes:

1. Oil equivalent is calculated based on oil, marketable gas, and condensate quantities.

2. Marketable gas is converted to oil equivalent on a field-by-field basis using an energy equivalent factor reflecting the reservoir gas composition of each field.

In our opinion, the information relating to estimated proved reserves of oil, condensate, natural gas liquids, and gas contained in this report has been prepared in accordance with Paragraphs 932-235-50-4, 932-235-50-6, 932-235-50-7, and 932-235-50-9 of the Accounting Standards Update 932-235-50, Extractive Industries – Oil and Gas (Topic 932): Oil and Gas Reserve Estimation and Disclosures (January 2010) of the Financial Accounting Standards Board and Rules 4–10(a) (1)–(32) of Regulation S–X and Rules 302(b), 1201, and 1202(a) (1), (2), (3), (4), (8) of Regulation S–K of the Securities and Exchange Commission; provided, however, that estimates of proved developed and proved undeveloped reserves are not presented at the beginning of the year.

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DEGOLYER AND MACNAUGHTON

To the extent the above-enumerated rules, regulations, and statements require determinations of an accounting or legal nature, we, as engineers, are necessarily unable to express an opinion as to whether the above-described information is in accordance therewith or sufficient therefor.

In comparing the detailed net proved reserves estimates prepared by DeGolyer and MacNaughton and by PEP, differences have been found, both positive and negative, resulting in an aggregate difference of 5.7 percent when compared on the basis of net oil equivalent barrels. It is DeGolyer and MacNaughton’s opinion that the net proved reserves estimates prepared by PEP on the properties reviewed and referred to above, when compared on the basis of net oil equivalent barrels, in aggregate, are considered reasonable.

DeGolyer and MacNaughton 1s an independent petroleum engineering consulting firm that has been providing petroleum consulting services throughout the world since 1936. DeGolyer and MacNaughton does not have any financial interest, including stock ownership, in PEP. Our fees were not contingent on the results of our evaluation. This letter report has been prepared at the request of PEP. DeGolyer and MacNaughton has used all assumptions, data, procedures, and methods that it considers necessary and appropriate to prepare this report.

Submitted,

DeGOLYER and MacNAUGHTON

Texas Registered Engineering Firm F-716

Thomas C. Pence, P.E.

Senior Vice President

DeGolyer and MacNaughton

DEGOLYER AND MACNAUGHTON

CERTIFICATE of QUALIFICATION

I, Thomas C. Pence, Petroleum Engineer with DeGolyer and MacNaughton, 5001 Spring Valley Road, Suite 800 East, Dallas, Texas, 75244 U.S.A., hereby certify:

1. That I am a Senior Vice President of DeGolyer and MacNaughton, which company did prepare the letter report addressed to PEP dated April 20, 2018, and that I, as Senior Vice President, was responsible for the preparation of this letter report.

2. That I attended Texas A&M University, and that I graduated with a degree in Petroleum Engineering in the year 1982; that I am a Registered Professional Engineer in the State of Texas; that I am a member of the International Society of Petroleum Engineers; and that I have in excess of 35 years of experience in oil and gas reservoir studies and reserves evaluations.

                                    

Thomas C. Pence, P.E.

Senior Vice President

DeGolyer and MacNaughton

Exhibit 10.6

(Part 2 of 2)

DEGOLYER AND MACNAUGHTON

5001 SPRING VALLEY ROAD

SUITE 800 EAST

DALLAS, TEXAS 75244

This is a digital representation of a DeGolyer and MacNaughton report.

This file is intended to be a manifestation of certain data in the subject report and as such are subject to the same conditions thereof. The information and data contained in this file may be subject to misinterpretation; therefore, the signed and bound copy of this report should be considered the only authoritative source of such information.

DEGOLYER AND MACNAUGHTON

5001 SPRING VALLEY ROAD

SUITE 800 EAST

DALLAS, TEXAS 75244

April 20, 2018

Ing. J. Javier Hinojosa Puebla

Director General de Pemex Exploración y Producción

Avenida Marina Nacional 329

Torre Ejecutiva, Piso 41

Col. Verónica Anzures, C.P. 11300

Del. Miguel Hidalgo, Ciudad de México

Dear Ing. Hinojosa,

Pursuant to your request, DeGolyer and MacNaughton has conducted an independent reserves evaluation of the net proved oil, gas, condensate, and oil equivalent reserves, as of January 1, 2018, of certain properties that PEMEX Exploración y Producción (PEP) has represented are owned by the United Mexican States in the Veracruz area of Mexico. This evaluation was completed on February 15, 2018. PEP has represented that these properties account for 2.3 percent on a net oil equivalent barrel basis of the net proved reserves assigned to PEP, as of January 1, 2018, and that the net proved reserves estimates have been prepared in accordance with the reserves definitions of Rules 4–10(a) (1)–(32) of Regulation S–X of the Securities and Exchange Commission (SEC) of the United States. At the request of PEP, this report also includes estimates prepared by PEP of its natural gas liquids (NGL) reserves; however, PEP has represented that PEP’s management of the properties stops at the inlet of the gas processing plants. PEP has represented that all subsurface hydrocarbons belong to the United Mexican States, and has further represented that PEP has received a 100-percent assignment in these properties by the United Mexican States; therefore, gross reserves are equal to net reserves and are defined as the total estimated petroleum to be produced from these properties after December 31, 2017. We have reviewed information provided to us by PEP that it represents to be PEP’s estimates of the net proved reserves, as of January 1, 2018, for the same properties as those which we evaluated. This report was prepared in accordance with guidelines specified in Item 1202 (a)(8) of Regulation S-K and is to be used for inclusion in certain SEC filings by PEP.

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DEGOLYER AND MACNAUGHTON

Based on Mexico’s Energy Reform of 2014, PEP has represented that its estimates of the net proved reserves assigned to PEP presented in this report correspond to 100 percent of the total net proved reserves of the Veracruz area assigned to PEP, on an oil equivalent basis.

Reserves estimates included herein are expressed as net reserves as represented by PEP. Gross reserves are defined as the total estimated petroleum to be produced from these properties after December 31, 2017. Net reserves are defined as that portion of the gross reserves attributable to the interests owned by the United Mexican States after deducting all interests owned by others.

Estimates of oil, gas, condensate, NGL, and oil equivalent reserves should be regarded only as estimates that may change as further production history and additional information become available. Not only are such reserves estimates based on that information which is currently available, but such estimates are also subject to the uncertainties inherent in the application of judgmental factors in interpreting such information.

Data used in this evaluation were obtained from reviews with PEP personnel, from PEP files, from records on file with the appropriate regulatory agencies, and from public sources. In the preparation of this report we have relied, without independent verification, upon such information furnished by PEP with respect to property interests, production from such properties, current costs of operation and development, current prices for production, agreements relating to current and future operations and sale of production, and various other information and data that were accepted as represented. A field examination of the properties was not considered necessary for the purposes of this report.

Methodology and Procedures

Estimates of reserves were prepared by the use of appropriate geologic, petroleum engineering, and evaluation principles and techniques that are in accordance with practices generally recognized by the petroleum industry as presented in the publication of the Society of Petroleum Engineers entitled “Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information (Revision as of February 19, 2007).” The method or combination of methods used in the analysis of each reservoir was tempered by experience with similar reservoirs, stage of development, quality and completeness of basic data, and production history.

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DEGOLYER AND MACNAUGHTON

Based on the current stage of field development, production performance, the development plans provided by PEP, and analyses of areas offsetting existing wells with test or production data, reserves were classified as proved.

When applicable, the volumetric method was used to estimate the original oil in place (OOIP) and the original gas in place (OGIP). Structure and isopach maps were constructed to estimate reservoir volume. Electrical logs, radioactivity logs, core analyses, and other available data were used to prepare these maps as well as to estimate representative values for porosity and water saturation. When adequate data were available and when circumstances justified, material balance and other engineering methods were used to estimate OOIP or OGIP.

Estimates of ultimate recovery were obtained after applying recovery factors to OOIP or OGIP. These recovery factors were based on consideration of the type of energy inherent in the reservoirs, analyses of the petroleum, the structural positions of the properties, and the production histories. When applicable, material balance and other engineering methods were used to estimate recovery factors. In such cases, an analysis of reservoir performance, including production rate, reservoir pressure, and gas-oil ratio behavior, was used in the estimation of reserves.

For depletion-type reservoirs or those whose performance disclosed a reliable decline in producing-rate trends or other diagnostic characteristics, reserves were estimated by the application of appropriate decline curves or other performance relationships. In the analyses of production-decline curves, reserves were estimated only to the limits of economic production based on existing economic conditions.

Gas quantities estimated herein are expressed as marketable gas and sales gas at a temperature base of 20 degrees Celsius and at a pressure base of 1 atmosphere. Marketable gas is defined as the total gas in the reservoirs to be produced after shrinkage resulting from field separation and flare. Marketable gas includes fuel. Sales gas is defined as the total gas to be produced from the reservoirs, measured at the point of delivery, after reduction for injection, fuel usage, flare, and shrinkage resulting from field separation and plant processing. Oil, condensate, and NGL reserves estimated herein are expressed in terms of 42 United States gallons per barrel. Oil and condensate reserves estimated herein are to be recovered by normal field separation. PEP has represented that its NGL reserves have been estimated on the basis of the quantities of liquids recovered from gas delivered to a gas plant for processing, and can include propane, butane, and C5+ fractions.

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DEGOLYER AND MACNAUGHTON

Definition of Reserves

Petroleum reserves estimated by PEP included in this report are classified as proved. Only proved reserves have been evaluated for this report. Reserves classifications used by PEP in this report are in accordance with the reserves definitions of Rules 4–10(a) (1)–(32) of Regulation S–X of the SEC. Reserves are judged to be economically producible in future years from known reservoirs under existing economic and operating conditions and assuming continuation of current regulatory practices using conventional production methods and equipment. In the analyses of production-decline curves, reserves were estimated only to the limit of economic rates of production under existing economic and operating conditions using prices and costs consistent with the effective date of this report, including consideration of changes in existing prices provided only by contractual arrangements but not including escalations based upon future conditions. The petroleum reserves are classified as follows:

Proved oil and gas reserves – Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.

(i) The area of the reservoir considered as proved includes:

(A) The area identified by drilling and limited by fluid contacts, if any, and (B) Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.

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DEGOLYER AND MACNAUGHTON

(ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty.

(iii) Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty.

(iv) Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when:

(A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and (B) The project has been approved for development by all necessary parties and entities, including governmental entities.

(v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.

Developed oil and gas reserves – Developed oil and gas reserves are reserves of any category that can be expected to be recovered:

(i) Through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and

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DEGOLYER AND MACNAUGHTON

(ii) Through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well.

Undeveloped oil and gas reserves – Undeveloped oil and gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion.

(i) Reserves on undrilled acreage shall be limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances.

(ii) Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances justify a longer time.

(iii) Under no circumstances shall estimates for undeveloped reserves be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, as defined in [section 210.4–10 (a) Definitions], or by other evidence using reliable technology establishing reasonable certainty.

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DEGOLYER AND MACNAUGHTON

Primary Economic Assumptions

The following economic assumptions were used for estimating existing and future prices and costs, expressed in United States dollars (U.S.$):

Oil and Condensate Prices

PEP has represented that the oil and condensate prices were based on a reference price, calculated as the unweighted arithmetic average of the first-day-of-the-month price for each month within the 12-month period prior to the end of the reporting period. As represented by PEP, the reference price utilized is the Mexican Mix reference price, which is composed of the Istmo, Maya, and Olmeca reference prices and is calculated based on a formula that includes the West Texas Sour, Light Louisiana Sweet, Brent, Oman, and Dubai reference prices. PEP supplied differentials by field to an average Mexican Mix reference price of U.S.$52.32 per barrel and the prices were held constant thereafter. The volume-weighted average adjusted prices attributable to estimated proved reserves for the fields that were evaluated were U.S.$49.64 per barrel for oil and U.S.$50.06 per barrel for condensate. These prices were not escalated for inflation.

Gas Prices

PEP has represented that the gas prices were based on a 12-month average price, calculated as the unweighted arithmetic average of the first-day-of-the-month price for each month within the 12-month period prior to the end of the reporting period, unless prices are defined by contractual arrangements. Each field’s calorific value, which includes NGL, was used to determine each field’s gas price. The volume-weighted average adjusted price for the fields that were evaluated was U.S.$3.81 per thousand cubic feet. These prices were not escalated for inflation.

Operating Expenses, Capital Costs, and Abandonment Costs

Operating expenses and capital costs, based on information provided by PEP, were used in estimating future costs required to operate the properties. In certain cases, future costs, either higher or lower than existing costs, may have been used because of anticipated changes in operating conditions. These costs were not escalated for inflation. Abandonment costs were provided by PEP.

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DEGOLYER AND MACNAUGHTON

While the oil and gas industry may be subject to regulatory changes from time to time that could affect an industry participant’s ability to recover its reserves, we are not aware of any such governmental actions which would restrict the recovery of the January 1, 2018, estimated reserves.

PEP has represented that its estimated net proved reserves attributable to the reviewed properties were based on the definition of proved reserves of the SEC. PEP has represented that its estimates of the net proved reserves attributable to these properties, which represent 2.3 percent of PEP’s reserves on a net oil equivalent basis, are summarized as follows, expressed in millions of barrels (MMbbl), billions of cubic feet (Bcf), and millions of barrels of oil equivalent (MMboe):

Estimated by PEP Net Proved Reserves as of January 1, 2018

Properties Reviewed by DeGolyer and MacNaughton

Oil (MMbbl)

Marketable Gas (Bcf)

Sales Gas (Bcf)

Condensate (MMbbl)

NGL (MMbbl)

Oil Equivalent (MMboe)

Veracruz Area

Total Proved

71.34

597.49

561.65

0.35

0.63

180.04

Notes:

1. Oil equivalent is calculated based on oil, marketable gas, and condensate quantities.

2. Marketable gas is converted to oil equivalent on a field-by-field basis using an energy equivalent factor reflecting the reservoir gas composition of each field.

In our opinion, the information relating to estimated proved reserves of oil, condensate, natural gas liquids, and gas contained in this report has been prepared in accordance with Paragraphs 932-235-50-4, 932-235-50-6, 932-235-50-7, and 932-235-50-9 of the Accounting Standards Update 932-235-50, Extractive Industries – Oil and Gas (Topic 932): Oil and Gas Reserve Estimation and Disclosures (January 2010) of the Financial Accounting Standards Board and Rules 4–10(a) (1)–(32) of Regulation S–X and Rules 302(b), 1201, and 1202(a) (1), (2), (3), (4), (8) of Regulation S–K of the Securities and Exchange Commission; provided, however, that estimates of proved developed and proved undeveloped reserves are not presented at the beginning of the year.

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DEGOLYER AND MACNAUGHTON

To the extent the above-enumerated rules, regulations, and statements require determinations of an accounting or legal nature, we, as engineers, are necessarily unable to express an opinion as to whether the above-described information is in accordance therewith or sufficient therefor.

In comparing the detailed net proved reserves estimates prepared by DeGolyer and MacNaughton and by PEP, differences have been found, both positive and negative, resulting in an aggregate difference of 3.8 percent when compared on the basis of net oil equivalent barrels. It is DeGolyer and MacNaughton’s opinion that the net proved reserves estimates prepared by PEP on the properties reviewed and referred to above, when compared on the basis of net oil equivalent barrels, in aggregate, do not differ materially from those prepared us.

DeGolyer and MacNaughton is an independent petroleum engineering consulting firm that has been providing petroleum consulting services throughout the world since 1936. DeGolyer and MacNaughton does not have any financial interest, including stock ownership, in PEP. Our fees were not contingent on the results of our evaluation. This letter report has been prepared at the request of PEP. DeGolyer and MacNaughton has used all assumptions, data, procedures, and methods that it considers necessary and appropriate to prepare this report.

Submitted,

DeGOLYER and MacNAUGHTON

Texas Registered Engineering Firm F-716

Thomas C. Pence, P.E.

Senior Vice President

DeGolyer and MacNaughton

DEGOLYER AND MACNAUGHTON

CERTIFICATE of QUALIFICATION

I, Thomas C. Pence, Petroleum Engineer with DeGolyer and MacNaughton, 5001 Spring Valley Road, Suite 800 East, Dallas, Texas, 75244 U.S.A., hereby certify:

1. That I am a Senior Vice President of DeGolyer and MacNaughton, which company did prepare the letter report addressed to PEP dated April 20, 2018, and that I, as Senior Vice President, was responsible for the preparation of this letter report.

2. That I attended Texas A&M University, and that I graduated with a degree in Petroleum Engineering in the year 1982; that I am a Registered Professional Engineer in the State of Texas; that I am a member of the International Society of Petroleum Engineers; and that I have in excess of 35 years of experience in oil and gas reservoir studies and reserves evaluations.

                                                 

Thomas C. Pence, P.E.

Senior Vice President

DeGolyer and MacNaughton

EX-12.1

Exhibit 12.1

CERTIFICATION

I, Carlos Alberto Treviño Medina, certify that:

1.    I have reviewed this annual report on Form 20-F of Petróleos Mexicanos;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the company as of, and for, the periods presented in this report;

4.    The company’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the company and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the company, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)    Evaluated the effectiveness of the company’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)    Disclosed in this report any change in the company’s internal control over financial reporting that occurred during the period covered by the annual report that has materially affected, or is reasonably likely to materially affect, the company’s internal control over financial reporting; and

5.    The company’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the company’s auditors and the audit committee of the company’s board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the company’s ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the company’s internal control over financial reporting.

Date: April 30, 2018

By:	/s/ CARLOS ALBERTO TREVIÑO MEDINA
Name:	Carlos Alberto Treviño Medina
Title:	Chief Executive Officer/Director General

EX-12.2

Exhibit 12.2

CERTIFICATION

I, David Ruelas Rodríguez, certify that:

1.    I have reviewed this annual report on Form 20-F of Petróleos Mexicanos;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the company as of, and for, the periods presented in this report;

4.    The company’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the company and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the company, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)    Evaluated the effectiveness of the company’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)    Disclosed in this report any change in the company’s internal control over financial reporting that occurred during the period covered by the annual report that has materially affected, or is reasonably likely to materially affect, the company’s internal control over financial reporting; and

5.    The company’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the company’s auditors and the audit committee of the company’s board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the company’s ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the company’s internal control over financial reporting.

Date: April 30, 2018

By:	/s/ DAVID RUELAS RODRÍGUEZ
Name:	David Ruelas Rodríguez
Title:	Chief Financial Officer/Corporate
	Director of Finance

EX-13.1

Exhibit 13.1

Certification

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

(Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code)

Pursuant to section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of section 1350, chapter 63 of title 18, United States Code), each of the undersigned officers of Petróleos Mexicanos, a productive state-owned company of the Federal Government of the United Mexican States (the “Company”), does hereby certify, to such officer’s knowledge, that:

The Annual Report on Form 20-F for the year ended December 31, 2016 (the “Form 20-F”) of the Company fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 and information contained in the Form 20-F fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: April 30, 2018

	By:	/S/ CARLOS ALBERTO TREVIÑO MEDINA
	Name:	Carlos Alberto Treviño Medina
	Title:	Chief Executive Officer/Director General
Date: April 30, 2018
	By:	/S/ DAVID RUELAS RODRÍGUEZ
	Name:	David Ruelas Rodríguez
	Title:	Chief Financial Officer/Corporate Director of Finance

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Document and Entity Information	12 Months Ended
	Dec. 31, 2017 shares
Document - Document and Entity Information [Abstract]
Document Type	20-F
Amendment Flag	false
Document Period End Date	Dec. 31, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	FY
Trading Symbol	CK0000932782
Entity Registrant Name	MEXICAN PETROLEUM
Entity Central Index Key	0000932782
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Current Reporting Status	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding	0

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Consolidated Statements of Financial Position $ in Thousands, $ in Thousands	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)
Current assets:
Cash and cash equivalents	$ 4,945,330	$ 97,851,754	$ 163,532,513
Accounts receivable, net	8,624,239	170,645,234	133,220,527
Inventories, net	3,227,366	63,858,930	45,892,060
Held-for-sale current non-financial assets		1,056,918	7,460,674
Available-for-sale financial assets	53,416	1,056,918	2,852,679
Derivative financial instruments	1,521,904	30,113,454	4,857,470
Total current assets	18,372,255	363,526,290	357,815,923
Non-current assets:
Available-for-sale financial assets			6,027,540
Investments in joint ventures and associates	844,373	16,707,364	20,737,509
Wells, pipelines, properties, plant and equipment, net	72,599,743	1,436,509,326	1,667,742,248
Long-term notes receivable	7,504,683	148,492,909	148,607,602
Deferred taxes	7,388,422	146,192,485	100,324,689
Restricted cash			10,478,626
Intangible assets	459,327	9,088,563	8,639,242
Other assets	580,449	11,485,177	9,512,645
Total non-current assets	89,376,997	1,768,475,824	1,972,070,101
Total assets	107,749,252	2,132,002,114	2,329,886,024
Current liabilities:
Short-term debt and current portion of long-term debt	7,945,209	157,209,467	176,166,188
Suppliers	7,073,205	139,955,378	151,649,540
Taxes and duties payable	2,577,740	51,004,960	48,839,595
Accounts and accrued expenses payable	1,173,081	23,211,401	18,666,607
Derivative financial instruments	896,864	17,745,979	30,867,956
Total current liabilities	19,666,099	389,127,185	426,189,886
Long-term liabilities:
Long-term debt	95,046,956	1,880,665,604	1,807,004,542
Employee benefits	63,600,101	1,258,436,122	1,220,409,436
Provisions for sundry creditors	4,431,129	87,677,423	88,317,878
Other liabilities	717,363	14,194,237	16,837,893
Deferred taxes	214,988	4,253,928	4,134,536
Total long-term liabilities	164,010,537	3,245,227,314	3,136,704,285
Total liabilities	183,676,636	3,634,354,499	3,562,894,171
Controlling interest:
Certificates of Contribution "A"	18,019,399	356,544,447	356,544,447
Mexican Government contributions	2,210,100	43,730,591	43,730,591
Legal reserve	50,647	1,002,130	1,002,130
Accumulated other comprehensive result	(7,676,226)	(151,887,182)	(163,399,441)
Accumulated deficit:
From prior years	(74,386,461)	(1,471,862,579)	(1,280,216,973)
Net loss for the year	(14,193,620)	(280,844,899)	(191,645,606)
Total controlling interest	(75,976,160)	(1,503,317,492)	(1,233,984,852)
Total non-controlling interest	48,776	965,107	976,705
Total equity (deficit), net	(75,927,384)	(1,502,352,385)	(1,233,008,147)
Total liabilities and equity (deficit), net	$ 107,749,252	$ 2,132,002,114	$ 2,329,886,024

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Consolidated Statements of Comprehensive Income $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Net sales:
Domestic	$ 44,340,898	$ 877,360,038	$ 670,000,473	$ 746,235,912
Export	25,701,057	508,539,112	395,118,117	407,214,445
Services income	562,528	11,130,569	8,974,642	8,310,035
Total of sales	70,604,483	1,397,029,719	1,074,093,232	1,161,760,392
Impairment (reversal) of wells, pipelines, properties, plant and equipment, net	7,653,856	151,444,560	(331,314,343)	477,944,690
Benefit from change in pension plan				(92,177,089)
Cost of sales	50,751,509	1,004,204,880	865,822,221	891,964,606
Gross income (loss)	12,199,118	241,380,279	539,585,354	(115,971,815)
Other revenues (expenses), net	261,493	5,174,076	22,649,606	(875,487)
General expenses:
Distribution, transportation and sale expenses	1,106,282	21,889,670	25,231,240	28,928,639
Administrative expenses	6,061,620	119,939,454	112,653,533	112,472,095
Benefit from change in pension plan				(103,860,955)
Operating income	5,292,708	104,725,231	424,350,187	(154,387,081)
Financing income	817,006	16,165,853	13,749,255	14,990,859
Financing cost	(5,945,638)	(117,644,548)	(98,844,464)	(67,773,593)
Derivative financial instruments income (cost), net	1,280,574	25,338,324	(14,000,987)	(21,449,877)
Foreign exchange income (loss), net	1,171,702	23,184,122	(254,012,743)	(154,765,574)
Subtotal	(2,676,356)	(52,956,249)	(353,108,939)	(228,998,185)
Profit sharing in joint ventures and associates	18,216	360,440	2,135,845	2,318,115
Income (loss) before taxes, duties and other	2,634,569	52,129,422	73,377,093	(381,067,151)
Profit sharing duty, net	17,084,416	338,044,209	277,161,804	377,087,514
Income tax	(255,938)	(5,064,168)	(12,640,369)	(45,587,267)
Total duties, taxes and other	16,828,478	332,980,041	264,521,435	331,500,247
Net (loss) income	(14,193,909)	(280,850,619)	(191,144,342)	(712,567,398)
Items that will be reclassified subsequently to profit or loss:
Available-for-sale financial assets	281,206	5,564,130	207,817	(3,206,316)
Currency translation effect	(308,109)	(6,096,459)	21,386,903	13,262,101
Items that will not be reclassified subsequently to profit or loss:
Actuarial gains-employee benefits	608,424	12,038,710	106,277,761	78,556,569
Total other comprehensive results	581,521	11,506,381	127,872,481	88,612,354
Total comprehensive loss	(13,612,388)	(269,344,238)	(63,271,861)	(623,955,044)
Net loss attributable to:
Controlling interest	(14,193,620)	(280,844,899)	(191,645,606)	(712,434,997)
Non-controlling interest	(289)	(5,720)	501,264	(132,401)
Net (loss) income	(14,193,909)	(280,850,619)	(191,144,342)	(712,567,398)
Other comprehensive results attributable to:
Controlling interest	581,818	11,512,259	127,650,318	88,571,493
Non-controlling interest	(297)	(5,878)	222,163	40,861
Total other comprehensive results	581,521	11,506,381	127,872,481	88,612,354
Comprehensive (loss) income:
Controlling interest	(13,611,802)	(269,332,640)	(63,995,288)	(623,863,504)
Non-controlling interest	(586)	(11,598)	723,427	(91,540)
Total comprehensive loss	$ (13,612,388)	$ (269,344,238)	$ (63,271,861)	$ (623,955,044)

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Consolidated Statements of Changes in Equity (Deficit), Net $ in Thousands, $ in Thousands	USD ($)	MXN ($)	Increase in Certificates of Contribution "A" [member] MXN ($)	Certificates of Contribution "A" [member] USD ($)	Certificates of Contribution "A" [member] MXN ($)	Certificates of Contribution "A" [member] Increase in Certificates of Contribution "A" [member] MXN ($)	Mexican Government contributions [member] USD ($)	Mexican Government contributions [member] MXN ($)	Legal Reserve [member] USD ($)	Legal Reserve [member] MXN ($)	Accumulated other comprehensive income (loss) [member] Available-for-sale financial assets [member] MXN ($)	Accumulated other comprehensive income (loss) [member] Cumulative currency translation effect [member] USD ($)	Accumulated other comprehensive income (loss) [member] Cumulative currency translation effect [member] MXN ($)	Accumulated other comprehensive income (loss) [member] Actuarial (losses) gains on employee benefits effect [member] USD ($)	Accumulated other comprehensive income (loss) [member] Actuarial (losses) gains on employee benefits effect [member] MXN ($)	Accumulated deficit [member] USD ($)	Accumulated deficit [member] MXN ($)	Equity attributable to owners of parent [member] USD ($)	Equity attributable to owners of parent [member] MXN ($)	Equity attributable to owners of parent [member] Increase in Certificates of Contribution "A" [member] MXN ($)	Non-controlling interests [member] USD ($)	Non-controlling interests [member] MXN ($)
Beginning balance (From prior years [member]) at Dec. 31, 2014																	$ (552,808,762)
Beginning balance at Dec. 31, 2014		$ (767,720,854)			$ 134,604,835			$ 43,730,591		$ 1,002,130	$ (2,565,631)		$ 16,320,433		$ (408,349,268)				$ (768,065,672)			$ 344,818
Increase decrease through other contributions by owners			$ 60,000,000			$ 60,000,000														$ 60,000,000
Total comprehensive (loss) income		(623,955,044)									(3,206,316)		13,229,927		78,547,882		(712,434,997)		(623,863,504)			(91,540)
Balances as of December 31, 2017 (Unaudited U.S. dollars) (From prior years [member]) at Dec. 31, 2015																	(552,808,762)
Balances as of December 31, 2017 (Unaudited U.S. dollars) at Dec. 31, 2015		(1,331,675,898)			194,604,835			43,730,591		1,002,130	(5,771,947)		29,550,360		(329,801,386)		(712,434,997)		(1,331,929,176)			253,278
Transfer to accumulated deficit | From prior years [member]																	(712,434,997)
Transfer to accumulated deficit																	712,434,997
Increase decrease through other contributions by owners			$ 161,939,612			$ 161,939,612														$ 161,939,612
Reclassification of other comprehensive income | From prior years [member]																	(14,973,214)
Reclassification of other comprehensive income															14,973,214
Total comprehensive (loss) income		(63,271,861)									207,817		21,169,662		106,272,839		(191,645,606)		(63,995,288)			723,427
Balances as of December 31, 2017 (Unaudited U.S. dollars) (From prior years [member]) at Dec. 31, 2016																	(1,280,216,973)
Balances as of December 31, 2017 (Unaudited U.S. dollars) at Dec. 31, 2016		(1,233,008,147)			356,544,447			43,730,591		1,002,130	(5,564,130)		50,720,022		(208,555,333)		(191,645,606)		(1,233,984,852)			976,705
Transfer to accumulated deficit | From prior years [member]																	(191,645,606)
Transfer to accumulated deficit																	191,645,606
Total comprehensive (loss) income	$ (13,612,388)	(269,344,238)									$ 5,564,130		(6,087,010)		12,035,139		(280,844,899)		(269,332,640)			(11,598)
Balances as of December 31, 2017 (Unaudited U.S. dollars) (From prior years [member]) at Dec. 31, 2017																$ (74,386,461)	(1,471,862,579)
Balances as of December 31, 2017 (Unaudited U.S. dollars) at Dec. 31, 2017	$ (75,927,384)	$ (1,502,352,385)		$ 18,019,399	$ 356,544,447		$ 2,210,100	$ 43,730,591	$ 50,647	$ 1,002,130		$ 2,255,708	$ 44,633,012	$ (9,931,934)	$ (196,520,194)	$ (14,193,620)	$ (280,844,899)	$ (75,976,160)	$ (1,503,317,492)		$ 48,776	$ 965,107

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Consolidated Statements of Cash Flows $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Operating activities
Net (loss)	$ (14,193,909)	$ (280,850,619)	$ (191,144,342)	$ (712,567,398)
Depreciation and amortization	7,919,689	156,704,513	150,439,491	167,951,250
(Reversal) impairment of wells, pipelines, properties, plant and equipment	7,653,856	151,444,560	(331,314,343)	477,944,690
Unsuccessful wells	311,554	6,164,624	29,106,084	23,213,519
Exploration costs	(73,168)	(1,447,761)	(2,022,826)	(5,698,511)
Disposal of wells, pipelines, properties, plant and equipment	862,381	17,063,671	3,771,287	24,638,537
Loss in sale of fixed assets			27,882,480
Gain on sale of share in joint ventures and associates	(158,647)	(3,139,103)	(15,211,039)	(680,630)
Profit share in joint ventures and associates	(18,216)	(360,440)	(2,135,845)	(2,318,115)
Decrease on available-for-sale financial assets	68,743	1,360,205
Impairment of goodwill			4,007,018
Disposal of held-for-sale current non-financial assets	141,932	2,808,360
Dividends	(9,131)	(180,675)	(293,397)	(359,941)
Effects of net present value of reserve for well abandonment	392,890	7,774,000	11,968,966	(608,160)
Net loss on available-for-sale financial assets	178,087	3,523,748
Unrealized foreign exchange (income) loss	(843,265)	(16,685,439)	243,182,764	152,676,256
Interest expense	5,945,638	117,644,548	98,844,464	67,773,593
Net cash flows (used in) from operating activities	8,178,434	161,824,192	27,080,762	191,965,090
Derivative financial instruments	(1,939,584)	(38,377,961)	310,905	9,802,397
Accounts receivable	(1,370,831)	(27,124,228)	(55,104,439)	33,003,083
Inventories	(908,028)	(17,966,870)	(1,358,879)	6,167,728
Long-term receivables	5,796	114,693	(3,277,724)
Intangible assets	(261,094)	(5,166,184)	(19,745,821)
Other assets	(99,690)	(1,972,532)	(2,104,985)	(16,602,365)
Accounts payable and accrued expenses	229,689	4,544,794	3,097,660	1,002,403
Taxes and duties payable	19,144,463	378,805,745	311,015,217	384,109,597
Taxes and duties paid	(19,062,925)	(377,192,377)	(301,050,325)	(351,370,004)
Suppliers	(591,011)	(11,694,162)	(15,664,703)	51,135,948
Provisions for sundry creditors	(339,351)	(6,714,632)	(11,413,361)	(41,239,700)
Employee benefits	2,530,255	50,065,396	47,293,069	(116,022,232)
Deferred taxes	(2,312,079)	(45,748,404)	(43,802,181)	(53,014,159)
Net cash flows from (used in) operating activities	3,204,044	63,397,470	(41,898,083)	98,937,786
Investing activities
Acquisition of wells, pipelines, properties, plant and equipment	(4,642,485)	(91,859,465)	(151,408,480)	(253,514,001)
Proceeds from available-for-sale financial assets	405,668	8,026,836
Proceeds from the sale of associates	158,779	3,141,710	22,684,736	4,417,138
Proceeds from the sale of fixed assets			560,665
Investments in associates				(36,214)
Business acquisition			(4,329,769)
Net cash flows used in investing activities	(4,078,038)	(80,690,919)	(132,492,848)	(249,133,077)
Financing activities
Increase in equity due to Certificates of Contributions "A"			73,500,000	10,000,000
Loans obtained from financial institutions	35,615,614	704,715,468	841,991,767	378,971,078
Debt payments, principal only	(32,342,434)	(642,059,819)	(614,987,329)	(193,618,498)
Interest paid	(5,504,223)	(108,910,417)	(88,754,141)	(62,737,150)
Cash flows provided by financing activities:	(2,231,043)	(46,254,768)	211,750,297	132,615,430
Net (decrease) increase in cash and cash equivalents	(3,211,663)	(63,548,217)	37,359,366	(17,579,861)
Effects of foreign exchange on cash balances	(107,776)	(2,132,542)	16,804,267	8,960,213
Cash and cash equivalents at the beginning of the year	8,264,769	163,532,513	109,368,880	117,988,528
Cash and cash equivalents at the end of the year	$ 4,945,330	$ 97,851,754	$ 163,532,513	$ 109,368,880

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Structure and Business Operations of Petroleos Mexicanos, Subsidiary Entities and Subsidiary Companies

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Structure and Business Operations of Petroleos Mexicanos, Subsidiary Entities and Subsidiary Companies

NOTE 1. STRUCTURE AND BUSINESS OPERATIONS OF PETRÓLEOS MEXICANOS, SUBSIDIARY ENTITIES AND SUBSIDIARY COMPANIES

Petróleos Mexicanos was created by a decree issued by the Mexican Congress on June 7, 1938. The decree was published in the Diario Oficial de la Federación (“Official Gazette of the Federation”) on July 20, 1938 and came into effect on that date.

On December 20, 2013, the Decreto por el que se reforman y adicionan diversas disposiciones de la Constitución Política de los Estados Unidos Mexicanos, en Materia de Energía (Decree that amends and supplements various provisions of the Mexican Constitution relating to energy matters), was published in the Official Gazette of the Federation and came into effect on December 21, 2013 (the “Energy Reform Decree”). In accordance with the Energy Reform Decree, the Mexican Government will carry out the exploration and extraction of hydrocarbons in the United Mexican States (“Mexico”) through assignments to productive state-owned companies, as well as through agreements with productive state-owned companies and with other companies.

As part of the secondary legislation enacted in accordance with the Energy Reform Decree, on August 11, 2014, the Ley de Petróleos Mexicanos (the “Petróleos Mexicanos Law”) was published in the Official Gazette of the Federation. The Petróleos Mexicanos Law became effective on October 7, 2014, except for certain provisions. On December 2, 2014, the Secretaría de Energía (“Ministry of Energy”) published in the Official Gazette of the Federation the declaration pursuant to which the special regime governing Petróleos Mexicanos’ activities relating to productive state-owned subsidiaries, affiliates, compensation, assets, administrative liabilities, state dividend, budget and debt levels came into effect. On June 10, 2015 the Disposiciones Generales de Contratación para Petróleos Mexicanos y sus Empresas Productivas Subsidiarias (General Contracting Provisions for Petróleos Mexicanos and its productive state-owned subsidiaries) was published in the Official Gazette of the Federation and thereafter the special regime for acquisitions, leases, services and public works matters came into effect.

Once the Petróleos Mexicanos Law came into effect, Petróleos Mexicanos was transformed from a decentralized public entity to a productive state-owned company. Petróleos Mexicanos is a legal entity empowered to own property and carry on business in its own name with the purpose of carrying out exploration and extraction of crude oil and other hydrocarbons in Mexico. In addition, Petróleos Mexicanos performs activities related to refining, gas processing and engineering and research projects to create economic value and to increase the income of the Mexican Government, as its owner, while adhering to principles of equity and social and environmental responsibility.

The Subsidiary Entities, Pemex Exploración y Producción (Pemex Exploration and Production), Pemex Transformación Industrial (Pemex Industrial Transformation), Pemex Perforación y Servicios (Pemex Drilling and Services), Pemex Logística (Pemex Logistics), Pemex Cogeneración y Servicios (Pemex Cogeneration and Services), Pemex Fertilizantes (Pemex Fertilizers) and Pemex Etileno (Pemex Ethylene), are productive state-owned subsidiaries empowered to own property and carry on business in their own name, subject to the direction and coordination of Petróleos Mexicanos (the “Subsidiary Entities”).

The Subsidiary Entities of Petróleos Mexicanos prior to the Corporate Reorganization (defined below) were Pemex-Exploración y Producción, Pemex-Refinación (Pemex-Refining), Pemex-Gas and Petroquímica Básica (Pemex-Gas and Basic Petrochemicals) and Pemex-Petroquímica (Pemex-Petrochemicals), which were decentralized public entities with a technical, industrial and commercial nature with their own corporate identity and equity, with the legal authority to own property and conduct business in their own names, and were 100% owned by Petróleos Mexicanos and controlled by the Mexican Government; they had been consolidated into and had the characteristics of subsidiaries of Petróleos Mexicanos.

The Board of Directors of Petróleos Mexicanos, in its meeting held on November 18, 2014, approved the Corporate Reorganization proposed by the Chief Executive Officer of Petróleos Mexicanos.

Pursuant to the corporate reorganization, the existing four Subsidiary Entities were transformed into two new productive state-owned subsidiaries, which have assumed all of the rights and obligations of the existing Subsidiary Entities (the “Corporate Reorganization”). Pemex-Exploration and Production was transformed into Pemex Exploration and Production, a productive state-owned subsidiary, and Pemex-Refining, Pemex-Gas and Basic Petrochemicals and Pemex-Petrochemicals were transformed into the productive state-owned subsidiary Pemex Industrial Transformation.

The Board of Directors of Petróleos Mexicanos also approved the creation of the following new Subsidiary Entities: Pemex Drilling and Services, Pemex Logistics, Pemex Cogeneration and Services, Pemex Fertilizers and Pemex Ethylene. Each of these productive state-owned subsidiaries may be transformed into an affiliate of Petróleos Mexicanos if certain conditions set forth in the Petróleos Mexicanos Law are met.

On March 27, 2015, the Board of Directors of Petróleos Mexicanos approved the Estatuto Orgánico de Petróleos Mexicanos (Organic Statute of Petróleos Mexicanos) and the acuerdos de creación (creation resolutions) of each productive state-owned subsidiary. The Subsidiary Entities, and their primary purposes, are as follows:

• Pemex Exploration and Production: This entity is in charge of exploration and extraction of crude oil and solid, liquid or gaseous hydrocarbons in Mexico, in the exclusive economic zone of Mexico and abroad.

• Pemex Industrial Transformation: This entity performs activities related to refining, processing, importing, exporting, trading and the sale of hydrocarbons.

• Pemex Drilling and Services: This entity performs drilling services and repair and services of wells.

• Pemex Logistics: This entity provides transportation, storage and related services for crude oil, petroleum products and petrochemicals to PEMEX (as defined below) and other companies, through pipelines and maritime and terrestrial means, and provides guard and management services.

• Pemex Cogeneration and Services: This entity generates, supplies and trades electric and thermal energy, including but not limited to the energy and thermal power produced in power plants and cogeneration plants, as well as performing technical and management services related to these activities to PEMEX and other companies, by itself or through companies in which it participates directly or indirectly.

• Pemex Fertilizers: This entity produces, distributes and commercializes ammonia, fertilizers and its derivatives, as well as provides related services.

• Pemex Ethylene: This entity commercializes, distributes and trades methane, ethane and propylene, directly or through others.

On April 28, 2015 the creation resolutions of the seven productive state-owned subsidiaries were published in the Official Gazette of the Federation. Each creation resolution included a provision establishing that the creation resolution would come into effect once the required administrative procedures to start operations were in place and the Board of Directors of Petróleos Mexicanos issued and published a statement related to each creation resolution in the Official Gazette of the Federation.

On May 29, 2015 the statements related to the creation resolution of the productive state-owned subsidiary Pemex Exploration and Production and the productive state-owned subsidiary Pemex Cogeneration and Services issued by the Board of Directors of Petróleos Mexicanos were published in the Official Gazette of the Federation and, accordingly, these creation resolutions came into effect on June 1, 2015. On December 29, 2015 and May 12, 2016, modifications to the creation resolution of the productive state-owned subsidiary Pemex Exploration and Production were published in the Official Gazette of the Federation and became effective that same date, respectively.

On July 31, 2015, the statements related to the creation resolution of the productive state-owned subsidiary Pemex Drilling and Services, the productive state-owned subsidiary Pemex Fertilizers and the productive state-owned subsidiary Pemex Ethylene issued by the Board of Directors of Petróleos Mexicanos were published in the Official Gazette of the Federation and, accordingly, these creation resolutions came into effect on August 1, 2015.

On October 1, 2015, the statement related to the creation resolution of the productive state-owned subsidiary Pemex Logistics issued by the Board of Directors of Petróleos Mexicanos was published in the Official Gazette of the Federation and, accordingly, these creation resolutions came into effect on October 1, 2015.

On October 6, 2015, the statement related to the creation resolution of the productive state-owned subsidiary Pemex Industrial Transformation issued by the Board of Directors of Petróleos Mexicanos was published in the Official Gazette of the Federation and, accordingly, these creation resolutions came into effect on November 1, 2015.

As of the date of this report, all of the creation resolutions of the productive state-owned subsidiaries have come into effect.

The principal distinction between the Subsidiary Entities and the Subsidiary Companies (as defined below) is that the Subsidiary Entities are productive state-owned entities, whereas the Subsidiary Companies are affiliate companies that were formed in accordance with the applicable laws of each of the respective jurisdictions in which they were incorporated. The “Subsidiary Companies” are defined as those companies which are controlled, directly or indirectly, by Petróleos Mexicanos (see Note 3 a).

“Associates,” as used herein, means those companies in which Petróleos Mexicanos does not have effective control (see Note 3 a).

Petróleos Mexicanos, the Subsidiary Entities and the Subsidiary Companies are referred to collectively herein as “PEMEX.”

PEMEX’s address and its principal place of business is: Av. Marina Nacional No. 329, Col. Verónica Anzures, Delegación Miguel Hidalgo, 11300 Ciudad de México, México.

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Basis of Preparation

12 Months Ended

Dec. 31, 2017

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Basis of Preparation

NOTE 2. BASIS OF PREPARATION

a. Statement of compliance

PEMEX prepared its consolidated financial statements as of December 31, 2017 and 2016, and for the years ended December 31, 2017, 2016 and 2015, in accordance with International Financial Reporting Standards (“IFRS”) as issued by the International Accounting Standards Board (“IASB”).

On April 27, 2018, these consolidated financial statements under IFRS and the notes hereto were authorized for issuance by the following officers: Mr. Carlos Alberto Treviño Medina, Chief Executive Officer, Mr. David Ruelas Rodríguez, Chief Financial Officer, Mr. Manuel Salvador Cruz Flores, Deputy Director of Accounting and Tax Matters, and Mr. Oscar René Orozco Piliado, Associate Managing Director of Accounting.

These consolidated financial statements and the notes hereto as of December 31, 2017 were approved by the Board of Petróleos Mexicanos on April 17, 2018 with prior approval from the Audit Committee of the report of the Independent Registered Public Accountant, pursuant to the terms of Article 13 Fraction VI of the Petróleos Mexicanos Law, Article 104 Fraction III, paragraph a, of the Ley del Mercado de Valores (Securities Market Law), and of Article 33 Fraction I, paragraph a, section 3 and Article 78 of the Disposiciones de carácter general aplicables a las emisoras de valores y a otros participantes del mercado de valores (General provisions applicable to securities´ issuers and other participants of the securities market).

b. Basis of measurement and going concern

These consolidated financial statements have been prepared using the historical cost basis method, except where it is indicated that certain items have been measured using the fair value model, amortized cost, present value or value in use. The principal items measured at fair value are derivative financial instruments (“DFIs”); the principal item measured at amortized cost is debt, the principal item measured at present value is the provision for employee benefits and some components of wells, pipelines, properties, plant and equipment are measured at value in use.

Going concern

The consolidated financial statements have been prepared on a going concern basis, which assumes that PEMEX can meet its payment obligations.

For the years ended December 31, 2017 and 2016, PEMEX recognized a net loss of Ps. 280,850,619 and Ps. 191,144,342, respectively, caused mainly by sustained low international oil prices, the high tax burden applicable to the industry, the depreciation of the peso relative to the U.S. dollar and an impairment of non-financial assets. In addition, as of December 31, 2017 and 2016, PEMEX had a negative equity of Ps. 1,502,352,385 and Ps. 1,233,008,147, respectively; a negative working capital of Ps. 25,600,895 and Ps. 68,373,963, respectively; and net cash flows used in operating activities of Ps. 41,898,083 for the year ended December 31, 2016. However, net cash flows from operating activities were Ps. 63,397,470, for the year ended December 31, 2017.

PEMEX believes net cash flows from its operating and financing activities, including its availability of lines of credit with certain banks, will be sufficient to meet its working capital needs, debt service and capital expenditure requirements and maintain its financial strength and flexibility in the twelve months following the date of issuance of these consolidated financial statements.

PEMEX continues to implement actions and business strategies that enable it to operate competitively and efficiently and take advantage of benefits of the Energy Reform Decree, as further described below:

• 2017-2021 Business Plan: On November 3, 2016, PEMEX announced its business plan for the five-year period from 2017 through 2021, which is designed to improve cash flows, reduce net indebtedness, strengthen its financial balance, reduce financial losses in its national refining system and plan for continued cost-cutting and administrative discipline, as well as the establishment of additional strategic alliances and partnerships, including an intensive farm-out program. The business plan was prepared conservatively and does not include additional income from the disposal of assets.

• Plan for 2017: The 2017 actions under the business plan established certain objectives with respect to its Subsidiary Entities that were implemented as follows:

• Pemex Exploration and Production’s investments focused on the most profitable projects, as well as on farm-outs and other partnerships aimed at increasing hydrocarbon production.

• On March 3, 2017, Pemex Exploration and Production signed the first farm-out project with BHP-Billiton for the Trion project and entered into a partnership with Chevron Energía de Mexico, S. de R.L. de C.V. (“Chevron”) and INPEX Corporation (“INPEX”) for the rights to block 3 North of the Cinturón Plegado Perdido in the Gulf of Mexico, both in deep waters.

• On May 2, 2017, Pemex Exploration and Production entered into an agreement with the Comisión Nacional de Hidrocarburos, (National Hydrocarbon Commission, or “NHC”) for crude oil drilling under the shared shallow-water production scheme for Ek-Balam field in the Campeche Basin.

• On May 30, 2017, Petróleos Mexicanos obtained approval from the NHC for the assignment of a new area that includes Chachiquin, located in the Cinturón Plegado Perdido region in the deep waters of the Gulf of Mexico south of the maritime border with the U.S., and an area southwest of the Nobilis field.

• Similarly, on June 19, 2017, Pemex Exploration and Production was awarded exploration and production fields bidding process (“Rounds”) in Round 2.1 the rights to develop two blocks in shallow waters: Block 2, in partnership DEA Deutsche Erdoel Ag (“DEA”) and Block B in partnership with Ecopetrol Global Energy, S.L.U. (“Ecopetrol”). On September 25, 2017, Pemex Exploration and Production signed the corresponding contracts for the exploration and extraction of hydrocarbons with DEA and Ecopetrol.

• On October 4, 2017, Pemex Exploration and Production finalized two farm-outs for the optimization of the development of the onshore fields of Cárdenas-Mora and Ogarrio, with Cheiron Holdings Limited (“Cheiron”) and DEA companies, respectively.

• On November 3, 2017, Petróleos Mexicanos announced the discovery of onshore light crude oil and gas reservoirs at the Ixachi-1 well in the state of Veracruz, Mexico, which PEMEX believes may contain over 1,500 million barrels of oil equivalent in place, representing 3P reserves of around 350 million barrels of oil equivalent. PEMEX believes that this discovery represents its largest onshore discovery in 15 years and that production can be accelerated due to the proximity of the reservoirs to existing infrastructure and to the Sistema Nacional de Gasoductos (National Gas Pipeline System.)

• On December 18, 2017, Pemex Exploration and Production and Petrofac México, S.A. de C.V., together with the NHC, signed the exploration and extraction contract for the onshore fields Santuario and El Golpe, which are located in the state of Tabasco.

• Pemex Industrial Transformation worked in partnerships for auxiliary services and the reconfiguration of certain refineries. On September 1, 2017, Pemex Industrial Transformation executed the auxiliary services contract with Air Liquide México. S.A. de R.L. de C.V. for ensuring and efficient hydrogen supply for the Miguel Hidalgo Refinery in Tula, Hidalgo.

• In September, 2017, Pemex Industrial Transformation began the selection process for partners for the hydrogen supply projects for the Héctor R. Lara Sosa Refinery in Cadereyta, Nuevo León and the Francisco I. Madero Refinery in Ciudad Madero, Tamaulipas. In April 2018, Pemex Industrial Transformation entered into a long-term agreement with the German company Linde AG for the supply of hydrogen to its Madero refinery.

• Pemex Logistics is being transformed from a company designed to ensure that Petróleos Mexicanos and its subsidiaries are properly supplied to one that provides profitable and competitive services to multiple customers. On May 2, 2017, PEMEX announced the results of the first Open Season Public Auction held by Pemex Logistics whereby, on July 18, 2017, PEMEX signed the contracts with Andeavor (formerly Tesoro Corporation). Under the contracts, Andeavor may use PEMEX’s pipeline transportation and storage system in the northwest of Mexico. On December 18, 2017, the Comisión Reguladora de Energía (the Energy Regulatory Commission, or “ERC”) approved Phase 2 of the Open Season.

• PEMEX’s business plan also describes its goal to increase the profitability of Pemex Fertilizers, Pemex Ethylene and Pemex Drilling and Services through service contracts and partnerships for the modernization of their facilities. On July 6, 2017, Pemex Ethylene, successfully concluded an e-auction to allocate quantities of ethylene oxide, in which 100% of the volume available was placed at a market price and was higher than the historical price.

• Plan for 2018: The 2018 actions under the business plan also set out certain objectives that PEMEX expects to achieve with respect to its Subsidiary Entities as follows:

• On January 31, 2018, PEMEX successfully participated in bidding Round 2.4, and was awarded the assignment of four blocks, all of which are located in deep waters in the Gulf of Mexico. Pemex Exploration and Production and Royal Dutch Shell PLC (“Shell”) were awarded Block 2 of the Perdido area. The consortium formed by Pemex Exploration and Production, Chevron and INPEX was awarded area 22 of the Cuenca Salina province. Finally, PEMEX was assigned on an individual basis, Block 5 in the Perdido area and area 18 of the Mexican Range province.

• On March 27, 2018, Petróleos Mexicanos successfully participated in bidding Round 3.1 of the NHC tenders, and was awarded seven contractual areas in shallow waters, six of them in a consortium and one on an individual basis. Pemex Exploration and Production won four blocks in the Southeast Basins: two in consortium with French Total S.A., one with Shell and one on an individual basis, as well as three blocks corresponding to the province of Tampico-Misantla-Veracruz: two in partnership with Compañía Española de Petróleos (“CEPSA”) and DEA and one more in partnership with CEPSA.

These contracts are intended to contribute to increase the reserves and hydrocarbon production with the respective economic benefits.

• Pemex Exploration and Production will focus on maintaining production levels and developing farm-outs and associations with the aim of increasing its operations and, with time, the production of hydrocarbons in the mid-term. Pemex Exploration and Production will also accelerate the migration of integrated E&P contracts and financed public works contracts to Exploration and Extraction Contracts (“EEC”) and will focus on the rehabilitation and reincorporation activities of wells with production possibilities. In 2018, Pemex Exploration and Production will continue to promote actions that encourage efficiency and optimize costs.

• In order to continue to take advantage of the benefits of the Energy Reform and to ensure the economic sustainability of PEMEX, in 2018 and in the up-coming years, Pemex Exploration and Production will be focusing its efforts on the following strategies: (1) establishing a model of exploration that allows it to achieve the objective of incorporating and increasing proved reserves; (2) developing a master plan for the development of shales; (3) containing and reversing declines in the production of wells through reactivation and maintenance activities performed on closed wells through integrated services; (4) continuing with farm-outs to develop complex fields and leverage third-party resources; (5) establishing schemes, including strategic partnerships and alliances, to attract additional investment; (6) increasing revenues from hydrocarbons trading; and (7) strengthening operational efficiency and cost control.

• Pemex Industrial Transformation will continue to perform reconfiguration and auxiliary services for its refineries and to focus on the following strategies: (1) keeping its facilities safe and reliable, (2) improving the financial balance, (3) maintaining a market share in Mexico of over 65%; and (4) eliminating debts, which will help to improve its refining margin.

In addition to taking advantage of new business opportunities and arrangements provided by the Energy Reform, such as farm-outs, PEMEX also continues to take certain specific measures to improve its financial position, including the following:

• 2016 Budget Adjustment: In 2017, PEMEX developed actions from its Plan de Ajuste Presupuestal 2016 (“2016 Budget Adjustment Plan”) to reduce expenses which were included in its 2017-2021 Business Plan.

• Pension Reform. As of January 1, 2016, new employees are entitled to receive a defined contribution pension plan, pursuant to which both PEMEX and its employees contribute to each employee’s individual account, in contrast to the existing defined benefit pension plan, pursuant to which only PEMEX contributes. Additionally, in August 2017, PEMEX began the process of inviting existing employees to migrate from a defined benefit plan to a defined contribution plan, which will allow Pemex to decrease its employee benefits service cost and its employee benefits liability.

• Asset Sales. PEMEX continues to evaluate the divestiture of non-essential assets to obtain working capital and to focus on those activities considered as the most profitable. These projects include:

• On October 5, 2017, PEMEX announced the divestiture of its participation in the Ramones II Norte gas pipeline (50% interest of Pemex Industrial Transformation in Ductos y Energéticos del Norte, S. de R.L. de C.V., and 5% indirect interest of Pemex Industrial Transformation TAG Norte Holding, S. de R.L. de C.V.). On November 10, 2017, the Comisión Federal de Competencia Económica (the Federal Commission for Financial Competence) authorized the divestiture in Ductos y Energéticos del Norte, S. de R.L. de C.V., closing the operation on November 16, 2017. PEMEX estimates that TAG Norte Holding, S. de R.L. de C.V. divestiture will conclude in the first semester of 2018.

• Decreased Debt Financing: PEMEX decreased its financing during 2017 from Ps. 231,618,067 of net indebtedness in 2016 to a net indebtedness of Ps. 72,412,672 in 2017. In addition, PEMEX developed liability management transactions in accordance with market conditions and in order to improve its financial profile, with longer due dates and better interest rates, as described in Note 15 to these consolidated financial statements. As a result of this strategy, Standard & Poor’s and Fitch increased PEMEX’s ratings outlook from negative to stable. For the fiscal year of 2018, the Federal Income Law applicable to PEMEX authorized for Petróleos Mexicanos and its Subsidiary Entities an internal net debt up to Ps. 30,000,000 and an external net debt up to U.S.$ 6,182,800. In addition, PEMEX will continue to assess opportunities for liability management in accordance with market conditions. In addition, as of December 31, 2017, PEMEX has five syndicated lines of credit to manage its liquidity for U.S.$6,700,000 and Ps.23,500,000.

• New Budget: On July 14, 2017, the Board of Directors of Petróleos Mexicanos approved a proposal for the annual consolidated budget of Petróleos Mexicanos and its Subsidiaries Entities for 2018, which was subsequently approved by the Chamber of Deputies on November 9, 2017.

The consolidated annual budget of Petróleos Mexicanos and its Subsidiary Entities for 2018 is approximately Ps. 391,946,000, a 1.7% increase as compared to the Ps. 385,211,257 consolidated annual adjusted budget for 2017.

• The structural changes arising from the Energy Reform, and the actions taken by management are aimed at ensuring the continuity of PEMEX’s operations, reducing costs, generating more revenue and operating more efficiently.

• In 2017, PEMEX entered into a crude oil hedge program to partially protect its cash flows from decreases in the price of Mexican crude oil.

Petróleos Mexicanos and its Subsidiary Entities are not subject to the Ley de Concursos Mercantiles (the Bankruptcy Law) and none of PEMEX’s existing financing agreements include any clause that could lead to the demand for immediate payment of the respective debt due to having negative equity.

PEMEX prepared its consolidated financial statements as of December 31, 2017 and 2016 on a going concern basis. There are certain conditions that have generated important uncertainty and significant doubts concerning the entity’s ability to continue operating, including recurring net losses, negative working capital and negative equity. These financial statements do not contain any adjustments that would be required if they were not prepared on a going concern basis.

c. Functional and reporting currency and translation of foreign currency operations

These consolidated financial statements are presented in Mexican pesos, which is both PEMEX’s functional and reporting currency, due to the following:

i. the economic environment in which PEMEX operates is Mexico, where the legal currency is the Mexican peso;

ii. Petróleos Mexicanos and its Subsidiary Entities have budgetary autonomy, subject only to maintaining the financial balance (the difference between income and total net spending, including the financial cost of the public debt of the Mexican Government and the entities directly controlled by the Mexican Government) and the spending cap of personnel services proposed by SHCP and approved by the Mexican Congress, in Mexican pesos.

iii. Employee benefits provision was approximately 35% and 34% of PEMEX’s total liabilities as of December 31, 2017 and 2016, respectively. This provision is computed, denominated and payable in Mexican pesos; and

iv. cash flows for payment of general expenses, taxes and duties are realized in Mexican pesos.

Although the sales prices of several products are based on international U.S. dollar-indices, final domestic selling prices are governed by the economic and financial policies established by the Mexican Government. Accordingly, cash flows from domestic sales are generated and received in Mexican pesos.

Mexico’s monetary policy regulator, the Banco de México, requires that Mexican Government entities other than financial entities sell their foreign currency to the Banco de México in accordance with its terms, receiving Mexican pesos in exchange, which is the currency of legal tender in Mexico.

Translation of financial statements of foreign operations

The financial statements of foreign subsidiaries and associates are translated into the reporting currency by first identifying if the functional currency is different from the currency for recording the foreign operations, and, if so, the recording currency is translated into the functional currency and then into the reporting currency using the year-end exchange rate of each period for assets and liabilities reported in the consolidated statements of financial position; the historical exchange rate at the date of the transaction for equity items; and the weighted average exchange rate of the year for income and expenses reported in the statement of comprehensive income.

d. Terms definition

References in these consolidated financial statements and the related notes to “pesos” or “Ps.” refers to Mexican pesos, “U.S. dollars” or “US$” refers to dollars of the United States of America, “yen” or “¥” refers to Japanese yen, “euro” or “€” refers to the legal currency of the European Economic and Monetary Union, “Pounds sterling” or “£” refers to the legal currency of the United Kingdom, “Swiss francs” or “CHF” refers to the legal currency of the Swiss Confederation, “Canadian dollars” or “CAD” refers to the legal currency of Canada and “Australian dollars” or “AUD” refers to the legal currency of Australia. Figures in all currencies are presented in thousands of the relevant currency unit, except exchange rates and product and share prices.

e. Convenience translations

These consolidated financial statements are presented in Mexican pesos (reporting currency), which is the same as the recording currency and the functional currency of PEMEX. The U.S. dollar amounts shown in the consolidated statements of financial position, the consolidated statements of comprehensive income, the consolidated statements of changes in equity (deficit) and the consolidated statements of cash flows have been included solely for the convenience of the reader and are unaudited. Such amounts have been translated from amounts in pesos, as a matter of arithmetic computation only, at the exchange rate for the settlement of obligations in foreign currencies provided by Banco de México and SHCP at December 31, 2017 of Ps. 19.7867 per U.S. dollar. Translations herein should not be construed as a representation that the peso amounts have been or could be converted into U.S. dollars at the foregoing or any other rate.

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Significant Accounting Policies

12 Months Ended

Dec. 31, 2017

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Significant Accounting Policies

NOTE 3. Significant accounting policies

The preparation of the consolidated financial statements in accordance with IFRS requires the use of estimates and assumptions made by PEMEX’s management that affect the recorded amounts of assets and liabilities and the disclosures of contingent assets and liabilities as of the date of these consolidated financial statements, as well as the recorded amounts of income, costs and expenses during the year.

Significant estimates and underlying assumptions are reviewed, and the effects of such revisions are recognized in the years in which any estimates are revised and in any future periods affected by such revision.

Information about estimates, assumptions and critical accounting policies that have the most significant effects on the amounts recognized in the consolidated financial statements are described in the following notes:

• Note 3(e) Financial instruments—determination of fair values

• Note 3(h) Wells, pipelines, properties, plant and equipment, including the successful efforts method—economic feasibility determining to capitalize assets

• Note 3(j) Impairment of non-financial assets—cash flow estimates and discount rates determination

• Note 3(l) Provisions—environmental liabilities and retirement of assets

• Note 3(m) Employee benefits—actuarial assumptions and hypothesis

• Note 3(n) Income taxes and duties—assessment of deferred income tax asset recovery

• Note 3(p) Contingencies—assessment of likelihood of contingency

Actual results could differ from those estimates and assumptions.

Below is a summary of the principal accounting policies, which have been consistently applied to each of the years presented and followed by PEMEX in the preparation of its consolidated financial statements:

a. Basis of consolidation

The consolidated financial statements include those of Petróleos Mexicanos, the Subsidiary Entities and the Subsidiary Companies. All intercompany balances and transactions of the consolidated companies; income and expenses, as well as unrealized profits and losses resulting from operations between them have been eliminated in the preparation of the consolidated financial statements pursuant to IFRS 10, “Consolidated Financial Statements” (“IFRS 10”).

Unrealized gains arising from transactions with entities whose investment is accounted for using the equity method are eliminated against the investment to the extent of PEMEX’s participation in such entities. Unrealized losses are eliminated in the same way as unrealized gains but only to the extent that there is no evidence of impairment of the investment. If such evidence exists, PEMEX recognizes it in its consolidated financial statements.

Investment in subsidiaries

The Subsidiary Entities and Subsidiary Companies are consolidated from the date that control commences until the date that control ceases.

Petróleos Mexicanos controls a subsidiary when it is exposed to or has rights to variable returns from the company and has the ability to affect those returns through its power over the company.

The financial statements of the Subsidiary Entities and Subsidiary Companies have been prepared based on the same period of Petróleos Mexicanos’ consolidated financial statements applying the same accounting policies.

For more information about Subsidiary Companies, see Note 4.

Investments in associates and joint arrangements

Associates are those entities in which PEMEX has significant influence but not the power to control financial and operational decisions. It is presumed that there is significant influence when PEMEX owns directly or indirectly between 20% and 50% of voting rights in another entity.

Joint arrangements are those arrangements whereby two or more parties have joint control of an arrangement. A joint arrangement is either a joint venture, where both of the parties have rights to the net assets of the arrangements, or a joint operation, where the parties have both rights to the assets, and obligations for the liabilities relating to the arrangements.

Investments in associates and joint ventures are recognized based on the equity method and recorded initially at cost, including any goodwill identified on acquisition. With respect to joint operations, the assets, liabilities, income and expenses are recognized in relation to the share of each party and in accordance with the applicable IFRS for each of those items. The investment cost includes transaction costs.

These consolidated financial statements include the proportion of gains, losses and other comprehensive income corresponding to PEMEX’s share in each investee, once these items are adjusted to align with the accounting policies of PEMEX, from the date that significant influence and joint control begins to the date that such influence or joint control ceases.

When the value of the share of losses exceeds the value of PEMEX’s investment in an associate or joint venture, the carrying value of the investment, including any long-term investment, is reduced to zero and PEMEX ceases to recognize additional losses, except in cases where PEMEX is liable for obligations incurred by those associates and joint ventures.

For more information about associates and joint arrangements, see Note 11.

Non-controlling interests

The equity interests of third parties who do not have a controlling interest in the equity or comprehensive result of subsidiaries of PEMEX are presented in the consolidated statements of financial position, the consolidated statements of changes in equity (deficit) as “non-controlling interests” and as “net income and comprehensive income for the period, attributable to non-controlling interests,” in the consolidated statements of comprehensive income.

Changes in a parent’s ownership interest in a subsidiary that do not result in a loss of control are accounted for as equity transactions. In such circumstances, the carrying amounts of the controlling and non-controlling interests shall be adjusted to reflect the changes in their relative interests in the subsidiary.

Dividends in cash and assets other than cash

A liability for distributions of dividends in cash and non-cash assets to third parties is recognized when the distribution is authorized by the Board of Directors. The corresponding amount is recognized directly in equity.

Distributions of dividends in non-cash assets are measured at the fair value of the assets to be distributed. Changes relating to these measurements of the fair value, between the date on which the distribution is declared and the date when the assets are transferred, are recognized directly in equity.

When distributing non-cash assets, any difference between the carrying amount of the liability for distribution of dividends and the carrying amount of the assets distributed is recognized in the consolidated statements of comprehensive income.

b. Business combinations and goodwill

Business combinations are accounted for using the acquisition method. The cost of an acquisition is measured as the aggregate of the consideration transferred, measured as the acquisition date fair value, and the amount of any non-controlling interest in the acquiree.

When PEMEX acquires a business, it assesses the acquired assets and liabilities in order to appropriately classify and designate each, taking into account the contractual terms, economic circumstances and other pertinent conditions as of the date of the acquisition. This includes the separation of embedded derivatives in host contractors by the acquiree. Acquired petroleum reserves and resources that can be reliably measured are recognized separately in the assessment of fair values on acquisition. Other potential reserves and rights, for which fair values cannot be reliably measured, are not recognized separately, but instead are subsumed in goodwill.

For business combinations achieved in stages, any previously held equity interest is measured at its acquisition date fair value, and any resulting gain or loss is recognized in income or loss or other comprehensive income.

Any contingent consideration to be transferred by the acquirer will be recognized at fair value on the acquisition date. Contingent consideration classified as an asset or liability that is a financial instrument and within the scope of IAS 39 “Financial instruments: Recognition and Measurement” is measured at fair value, with changes in fair value recognized in income or loss or other comprehensive income. If contingent consideration is not with the scope of IAS 39, it is measured in accordance with the appropriate IFRS requirement. Contingent consideration that is classified as equity is not remeasured, and subsequent settlement is accounted for within equity.

Goodwill, which is initially measured at cost, is the excess of the aggregate of the consideration transferred and the amount recognized for non-controlling interest over the fair value of the identifiable net assets acquired and liabilities assumed. If the fair value of the net asset acquired is greater than the aggregate consideration transferred (bargain purchase), before recognizing a gain, PEMEX reassesses whether it has correctly identified all of the assets acquired and all of the liabilities assumed and reviews the procedures used to measure the amounts to be recognized at the acquisition date. If the assessment still results in an excess of the fair value of net assets acquired over the aggregate consideration transferred, then the gain is recognized in the consolidated statements of comprehensive income.

After initial recognition, goodwill is measured at cost less any accumulated impairment losses. For the purpose of impairment testing, goodwill acquired in a business combination is, from the acquisition date, allocated to each cash generating unit that is expected to benefit from the combination, irrespective of whether other assets or liabilities of the acquiree are assigned to those units.

When goodwill is allocated to a cash generating unit and certain of the operations in that unit are disposed of, the goodwill associated with the disposed operation is included in the carrying amount of the operation when determining the gain or loss on disposal. Goodwill disposed in these circumstances is measured based on the relative values of the disposed operation and the portion of the cash generating unit retained.

c. Transactions in foreign currency

In accordance with IAS 21, “The Effects of Changes in Foreign Exchange Rates” (“IAS 21”), transactions in foreign currencies are translated and recorded at exchange rates at the dates of the transactions and/or of the presentation of financial information.

Exchange differences arising from the settlement of monetary items or from the translation of monetary items into rates different from those at which they were translated on their initial recognition, are recognized in the results of operations in the reporting period in which they arise. When a gain or loss from a non-monetary item is recognized in other comprehensive results, any exchange difference included in that gain or loss is recognized in other comprehensive results. Conversely, when a gain or loss from a non-monetary item is recognized in the results of operations, any exchange difference included in that gain or loss is recognized in the results of operations for the period.

d. Fair value measurement

PEMEX measures certain financial instruments such as DFIs at fair value as of the closing date of the relevant reporting period.

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. A measurement at fair value assumes that the sale of the asset or transfer of a liability occurs:

i. in the principal market for the asset or liability; or

ii. in the absence of a principal market, in the most advantageous market for the asset or liability.

The principal market or the most advantageous market must be accessible for PEMEX.

The fair value of an asset or liability is measured by using the same assumptions that market participants would make when pricing the asset or liability under the premise that market participants take into account highest and best use of the asset or liability.

e. Financial instruments

Financial instruments are classified as: (i) financial instruments measured at fair value through profit or loss; (ii) financial instruments held to maturity; (iii) available-for-sale financial assets; (iv) investments in equity instruments; (v) loans and receivables; and (vi) DFIs. PEMEX determines the classification of its financial instruments at the time of initial recognition.

PEMEX’s financial instruments include cash and short-term deposits, available-for-sale financial assets, accounts receivable, other receivables, loans, accounts payable to suppliers, other accounts payable, borrowings and debts, as well as DFIs.

Below are descriptions of the financial instruments policies employed by PEMEX:

Financial instruments measured at fair value through profit or loss

A financial instrument is measured at fair value through profit or loss if it is classified as held for trading or designated as such upon initial recognition. Financial assets are designated at fair value through profit or loss if PEMEX manages such investments and makes purchase and sale decisions based on their fair value in accordance with PEMEX’s documented risk management or investment strategy. In addition, directly attributable transaction costs are recognized in the consolidated statements of comprehensive income for the year. These financial instruments are recognized at fair value and corresponding changes relating to dividend income are recognized in the consolidated statements of comprehensive income.

Available-for-sale financial assets

Available-for-sale financial assets are non-DFIs that are designated as available-for-sale or are not classified in any of the previous categories. PEMEX’s investments in certain equity securities and debt securities are classified as available-for-sale financial assets. Available-for-sale financial assets are recognized initially at fair value plus any directly attributable transaction costs.

Subsequent to initial recognition, available-for-sale financial assets are measured at fair value. In addition, any gains or losses associated with such instruments, as well as foreign exchange differences are recognized in other comprehensive results and presented in the fair value reserve in equity. When an investment is derecognized, any gains or losses accumulated in the equity are reclassified to profit or loss.

Sales and purchases of financial assets that require the delivery of such assets within a period of time established by market practice are recognized as of the negotiation date (the date on which PEMEX commits to purchase or sell the asset).

Loans and receivables

Loans and receivables are initially recognized at fair value. After initial recognition, loans and debt securities that bear interest are measured at amortized cost using the effective interest rate (“EIR”) method, less impairment losses.

The amortized cost is calculated based on any discount or premium on acquisition and fees and costs that are an integral part of the EIR method. Amortization of costs is included under the heading of financing cost in the consolidated statements of comprehensive income.

Derivative financial instruments

DFIs presented in the consolidated statements of financial position are carried at fair value. In the case of DFIs held for trading, changes in fair value are recorded in profit or loss; in the case of DFIs formally designated as and that qualify for hedging, changes in fair value are recorded in the consolidated statements of comprehensive income using cash flow or fair value hedge accounting, with gains or losses classified in accordance with the earnings treatment of the hedge transaction.

Embedded derivatives

PEMEX evaluates the potential existence of embedded derivatives, which may be found in the terms of its contracts, or combined with other host contracts, which could be structured financial instruments (debt or equity instruments with embedded derivatives). Embedded derivatives have terms that implicitly or explicitly meet the characteristics of a DFI. In some instances, these embedded derivatives must be segregated from the underlying contracts and measured, recognized, presented and disclosed as DFIs, such as when the economic risks and terms of the embedded derivative are not clearly and closely related to the underlying contract.

Impairment of financial assets

At each reporting date, PEMEX evaluates whether there is objective evidence that a financial asset or group of financial assets is impaired, in which case the value of the recoverable amount of the asset is calculated. A financial asset is impaired if objective evidence indicates that a loss event has occurred after the initial recognition of the asset, and that the loss event had a negative effect on the estimated future cash flows of the financial asset.

Objective evidence that a financial asset or group of assets is impaired includes significant financial difficulty of the issuer or obligor, a breach of contract, such as a default or delinquency in interest or principal payments; the lender, for economic or legal reasons relating to the borrower’s financial difficulty, granting to the borrower a concession that the lender would not otherwise consider; it becoming probable that the borrower will enter bankruptcy or other financial reorganization; the disappearance of an active market for that financial asset because of financial difficulties; or observable data indicating that there is a measurable decrease in the estimated future cash flows. Impairments by asset are:

Impairment of financial assets carried at amortized cost

The impairment of financial assets carried at amortized cost is measured as the difference between the assets carrying amount and the present value of estimated future cash flows (excluding future credit losses that have not been incurred) discounted at the financial asset’s original effective interest rate. The amount of the loss shall be recognized in profit or loss.

If, in a subsequent period, the amount of the impairment loss decreases and the decrease can be related objectively to an event occurring after the impairment was recognized, the impairment loss previously recognized shall be reversed in profit or loss.

Impairment in available—for—sale financial assets

In addition to the above-mentioned, a significant or prolonged decline in the fair value of an investment in an available—for—sale equity instrument is also objective evidence of impairment.

When there is objective evidence of the impairment of an asset, the accumulated loss recognized in other comprehensive income shall be reclassified from equity to profit or loss even though the financial asset has not been derecognized.

If, in a subsequent period, the impairment loss decreases, the reversal shall be reflected as a reversal in other comprehensive income.

f. Cash and cash equivalents

Cash and cash equivalents are comprised of cash balances on hand, net of overdrafts, deposits in bank accounts, foreign currency reserves and instruments with maturities of three months or less from the acquisition date that are subject to an insignificant risk of changes in their fair value, which are used in the management of PEMEX’s short-term commitments.

Cash subject to restrictions or that cannot be exchanged or used to settle a liability within 12 months is presented as non-current assets.

g. Inventories and cost of sales

Inventories are valued at the lower of cost or net realizable value. Cost is determined based on the cost of production or acquisition of inventory and other costs incurred in transporting such inventory to its present location and in its present condition, using the average cost formula. Net realizable value is the estimated selling price in the ordinary course of business less the estimated costs of completion and the estimated selling costs. The estimate takes into consideration, among other things, the decrease in the value of inventories due to obsolescence.

Cost of sales represents the cost of production or acquisition of inventories at the time of sale, increased, where appropriate, by declines in net realizable value of inventories during the year.

Advance payment to suppliers for inventory purchases are recognized as part of inventory when the risks and benefits of the ownership of the inventory have been transferred to PEMEX.

h. Wells, pipelines, properties, plant and equipment

Wells, pipelines, properties, plant and equipment are recorded at acquisition or construction cost less accumulated depreciation and accumulated impairment losses.

PEMEX uses the successful efforts method for the exploration and production of crude oil and gas activities, considering the criteria mentioned in IFRS 6, “Exploration for and Evaluation of Mineral Resources” in relation to the recognition of exploration and drilling assets. Costs of development wells and related plant, property and equipment involved in the exploitation of oil and gas are recorded as part of the cost of assets. The costs of exploratory wells in areas that have not yet been designated as containing proved reserves are recorded as intangible assets until it is determined whether they are commercially viable to capitalize as fixed assets, otherwise they are recognized as exploration expenses. Other expenditures on exploration are recognized as exploration expenses as they are incurred.

In accordance with IAS 16, “Property, Plant and Equipment” (“IAS 16”), initial costs of wells, pipelines, properties, plant and equipment are initially recorded at cost, which includes their original purchase price or construction cost, any costs attributable to bringing the assets to a working condition for their intended use and the costs of dismantling and removing the items and restoring the site on which they are located, including the estimated cost of plugging and abandoning wells.

The cost of financing projects that require large investments and financing incurred for projects, net of interest revenues from the temporary investment of these funds, is recognized as part of wells, pipelines, properties, plant and equipment when the cost is directly attributable to the construction or acquisition of a qualifying asset. The capitalization of these costs is suspended during periods in which the development of construction is interrupted, and its capitalization ends when the activities necessary for the use of the qualifying asset are substantially completed. All other financing costs are recognized in the consolidated statements of comprehensive income in the period in which they are incurred.

The cost of self-constructed assets includes the cost of materials and direct labor, interest on financing and any other costs directly attributable to start up. In some cases the cost also includes the cost of plugging of wells and removal.

Expenditures related to the construction of wells, pipelines, properties, plant and equipment during the stage prior to commissioning are stated at cost as intangible assets or construction in progress, in accordance with the characteristics of the asset. Once the assets are ready for use, they are transferred to the respective component of wells, pipelines, properties, plant and equipment and depreciation or amortization begins.

The costs of major maintenance or replacement of a significant component of an item of wells, pipelines, properties, plant and equipment are recognized in the carrying amount of the item if it is probable that the future economic benefits embodied within the component will flow to PEMEX and its cost can be measured reliably. The costs of recurring maintenance, repairs and renovations of wells, pipelines, properties, plant and equipment carried out to maintain the facilities in normal operation conditions are recognized in profit or loss as incurred.

Depreciation and amortization of capitalized costs in wells are determined based on the estimated economic life of the field to which the wells belong, considering the relationship between the production of barrels of oil equivalent for the period and proved developed reserves of the field, as of the beginning of the period, with quarterly updates for new development investments.

Depreciation of other elements of pipelines, properties, plant and equipment is recognized in profit or loss on a straight-line basis over the estimated useful life of the asset, beginning as of the date that the asset is available for use, or in the case of construction, from the date that the asset is completed and ready for use.

When parts of an item of wells, pipelines, properties and equipment are significant relative to the total cost of the item, the part is depreciated separately.

Estimated useful lives of items of properties, plant and equipment are reviewed if expectations differ from previous estimates.

Pipelines, properties, and equipment received from customers are initially recognized at fair value as revenue from ordinary operating activities if PEMEX has no future obligations to the customer who transferred the item. In contrast, if PEMEX does have future obligations to such a customer, the initial recognition is recorded as a deferred liability based on the period in which the assets will provide services to the customers.

The capitalized value of finance leases is also included in the line item of wells, pipelines, properties, plant and equipment. Properties, plant and equipment acquired through financial leases are depreciated over the shorter of the lease term or the useful life of the asset.

Advance payments for the acquisition of pipelines, properties, plant and equipment are also recognized in the line item of wells, pipelines, properties, plant and equipment when the risks and benefits of the ownership have been transferred to PEMEX.

i. Crude oil and natural gas reserves

Under Mexican law, all crude oil and other hydrocarbon reserves located in the subsoil of Mexico are owned by the Mexican nation and not by PEMEX. In accordance with the aforementioned and based on the applicable regulation as of the date of these consolidated financial statements, the reserves assigned to PEMEX by the Mexican Government are not registered for accounting purposes because they are not PEMEX’s property. PEMEX estimates total proved oil and natural gas reserve volumes in accordance with the definitions, methods and procedures established in Rule 4-10(a) of Regulation S-X (“Rule 4-10(a)”) of the U.S. Securities and Exchange Commission (“SEC”) as amended, and where necessary, in accordance with the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers (the “SPE”) as of February 19, 2007. These procedures are consistent with international reserves reporting practice. The estimation of these reserves depends on assumptions made and the interpretation of the data available, and may vary among analysts. The results of drilling activities, test wells and production after the date of estimation are utilized in future revisions of reserves estimates.

Although PEMEX does not own the oil and other hydrocarbon reserves within Mexico, these procedures allow PEMEX to record the effects that such oil and other hydrocarbon reserves have on its consolidated financial statements, including, for example, in the depreciation and amortization line item.

j. Impairment of non-financial assets

The carrying amounts of PEMEX’s non-financial assets, other than inventories and deferred taxes, are assessed for indicators of impairment at the end of each reporting period. If the net carrying value of the asset or its cash-generating unit exceeds the recoverable amount, PEMEX records an impairment charge in its consolidated statement of comprehensive income.

A cash-generating unit is the smallest identifiable group of assets which can generate cash flows independently from other assets or groups of assets.

The recoverable amount of an asset or a cash-generating unit is defined as the higher of its fair value minus the costs of disposal and its value in use. The value in use is the discounted present value of the net future cash flows expected to arise from the continuing use of an asset and from its disposal at the end of its useful life. In measuring value in use, the discount rate applied is the pre-tax rate that reflects current market assessments of the time value of money and the risks specific to the asset. Fair value is calculated using discounted cash flows determined by the assumptions that market participants would apply in order to estimate the price of an asset or cash generating unit, assuming that such participants were acting in their best economic interest.

In the case of cash-generating assets or items dedicated to the exploration and evaluation of hydrocarbons reserves, the recoverable amount is determined using the value in use based on the proved reserves and probable reserves, in some cases, for the risk factor associated with such reserves.

Both impairment losses and reversals are recognized in the statement of comprehensive income in the costs and expenses line items in which the depreciation and amortization are recognized. Impairment losses may not be presented as part of the costs that have been capitalized in the value of any asset. Impairment losses related to inventories are recognized as part of cost of sales. Impairment losses on investments in associates, joint ventures and other investments are recognized as profit (loss) sharing in associates.

An impairment loss shall be reversed if there has been a change in the estimates used since the date when the impairment loss was recognized. These reversals will not exceed the carrying value of the asset as though no impairment had been recognized. Impairment losses and reversals are presented in a separate line item in the statement of comprehensive income.

k. Leases

The determination of whether an agreement is or contains a lease is based on the economic substance of the agreement at the date of execution. An agreement contains a lease if performance under the agreement depends upon the use of a specific asset or assets, or if the agreement grants the right to use the asset.

Finance leases, which transfer to PEMEX substantially all the inherent benefits and risks of the leased property, are capitalized at the date the lease commences, and the value is recorded as the lower of the fair value of the leased property and the present value of the minimum lease payments. Payments on the lease are divided between the financial costs and the amortization of the remaining debt principal in order to achieve a constant effective interest rate for the outstanding liability. The financing costs are recognized in the statement of comprehensive income.

Operating lease payments are recognized as expenses in the statement of comprehensive income on a straight line basis over the term of the lease and variable rent payments are recognized in the operating results on an accrued basis.

l. Provisions

PEMEX recognizes provisions when, as a result of a past event, PEMEX has incurred a legal or assumed present obligation for which a future disbursement is probable and the value of such disbursement is reasonably estimable. In certain cases, such amounts are recorded at their present value.

Environmental liabilities

In accordance with applicable legal requirements and accounting practices, an environmental liability is recognized when the cash outflows are probable and the amount is reasonably estimable. Disbursements related to the conservation of the environment that are linked to revenue from current or future operations are accounted as expenses or assets, depending on the circumstances of each disbursement. Disbursements related to past operations, which no longer contribute to current or future revenues, are accounted for as current period expenses.

The accrual of a liability for a future disbursement occurs when an obligation related to environmental remediation, for which PEMEX has the information necessary to determine a reasonable estimated cost, is identified.

Retirement of assets

The obligations associated with the future retirement of assets, including those related to the retirement of wells, pipelines, properties, plant and equipment and their components are recognized at the date that the retirement obligation is incurred, based on the discounted cash flow method. The determination of the fair value is based on existing technology and regulations. If a reliable estimation of fair value cannot be made at the time the obligation is incurred, the accrual will be recognized when there is sufficient information to estimate the fair value.

The obligations related to the costs of future retirement of assets associated with the principal refining processes for gas and petrochemicals are not recognized. These assets are considered to have an indefinite useful life due to the potential for maintenance and repairs.

The abandonment costs related to wells currently in production and wells temporarily closed are recorded in the statement of comprehensive income based on the units of production method. Total cost of abandonment and plugging for non-producing wells is recognized in the statement of comprehensive income at the end of each period. All estimations are based on the useful lives of the wells, considering their discounted present value. Salvage values are not considered, as these values commonly have not traditionally existed.

m. Employee benefits

Beginning January 1, 2016, Petróleos Mexicanos and the Subsidiary Entities have operated both a defined contribution plan and a defined benefit pension plan. Until December 31, 2015, PEMEX only operated a defined benefit pension plan.

Defined contribution pension plan

In this plan, both Petróleos Mexicanos and the Subsidiary Entities and their respective employees contribute to the worker’s individual account. PEMEX’s contributions are recognized on an accrual basis as cost, expense or asset, and are credited to liability.

Contributions to the defined contribution plan that are not expected to be fully settled within 12 months after the end of the annual reporting period in which the employee rendered related services will be discounted using the defined benefit plan discount rate.

Defined benefit plan

Under the defined benefit plan, Petróleos Mexicanos and the Subsidiary Entities are the only parties that contribute to a trust, which is managed separately. Petróleos Mexicanos and the Subsidiary Entities recognize the cost for defined benefit plans based on independent actuarial computations applying the projected unit credit method. Actuarial gains and losses are recognized within other comprehensive results for the period in which they are determined.

The costs of prior services are recognized within profit or loss for the period in which they are determined.

The asset or liability in the defined benefit plan comprises the present value of the defined benefit obligation less the fair value of plan assets for which obligations have to be settled. The value of any asset is limited to the present value of any economic benefit represented by the plan reimbursements or reductions of the future contributions to the plan.

In addition, other long term employee benefits include the seniority premiums payable for disability, death and survivors benefits, medical services, gas and basic food basket for beneficiaries.

Termination benefits are recognized in profit or loss for the year in which they are incurred.

n. Income taxes and duties

Current income tax

Current income tax assets or liabilities for the current and prior years are measured as the amount expected to be paid or to be recovered from the tax authorities, using either the tax rates in force or tax rates which are in the process of being approved and are substantially completed by the end of the year.

Current income taxes related with items that are recognized as equity are presented in the other comprehensive income of the year. Periodically, PEMEX evaluates the positions taken in its tax returns for those regulations that are subject to interpretation and books corresponding provisions, if it is deemed necessary.

Deferred income taxes

Deferred taxes are recorded based on the assets and liabilities method, which consists of the recognition of deferred taxes by applying tax rates applicable to the income tax to the temporary differences between the carrying value and tax values of assets and liabilities at the date of these consolidated financial statements.

Deferred tax liabilities are recognized for all taxable temporary differences, except to the extent that the deferred tax liability arises from:

• the initial recognition of goodwill or the initial recognition of an asset or liability in a transaction which is not a business combination and at the time of the transaction, affects neither accounting profit nor taxable profit or tax loss; and

• taxable temporary differences associated with investments in subsidiaries, branches and associates, and interest in joint arrangements, when the parent, investor, joint venture or joint operator is able to control the timing of reversal of the temporary difference and it is probable that the temporary difference will not reverse in the foreseeable future.

Deferred tax assets are recognized for all deductible temporary differences and the carry forward of both unused tax credits and unused tax losses to the extent that it is probable that taxable profit will be available against deductible temporary differences, and that the carry forward of both unused tax credits and unused tax losses can be utilized, unless:

• the deferred tax asset relating to deductible temporary difference arises from the initial recognition of asset or liability derived from a transaction that is not a business combination and, at the time of the transaction, affects neither accounting profit nor taxable profit or tax loss; and

• in respect of deductible temporary differences associated with investments in subsidiaries, associates and interests in joint ventures, deferred tax assets are recognized only to the extent that it is probable that the temporary differences will reverse in the foreseeable future and taxable profit will be available, against which the temporary differences can be utilized.

The carrying amount of a deferred tax asset is reviewed at the end of each reporting period. PEMEX reduces the carrying amount of a deferred tax asset to the extent that it is no longer probable that a sufficient taxable profit will be available to allow the benefit of that deferred tax asset to be utilized in whole or in part. Unrecognized deferred tax assets are revalued at each reporting date and will be recognized to the extent that it is probable that future taxable income will be sufficient to allow for the recovery of the deferred tax asset.

Deferred tax assets and liabilities are measured at the tax rates that are expected to apply to the period when the asset is realized or the liability is settled, based on tax rates (and tax laws) that have been enacted or substantively enacted by the end of the reporting period.

Deferred tax assets and deferred tax liabilities related with items that are recognized in equity shall be presented directly in other comprehensive income.

Deferred tax assets and deferred tax liabilities are offset if PEMEX has a legal right to set off current tax assets against current tax liabilities and are levied by the same taxation authority or the same taxable entity.

Income taxes and duties

PEMEX is subject to taxes and special duties, which are based on the value of hydrocarbons extracted, with certain deductions.

These taxes and duties are recognized in accordance with IAS 12, “Income Taxes” (IAS 12), when they have the characteristics of income tax, which occurs when such taxes are set by a government authority and are determined on a formula that considers the balance of income (or extraction valued at a selling price) less expenses. Taxes and duties that meet this criteria should be recognized for current and deferred income tax based on the above paragraphs. Taxes and duties that do not meet this criteria are recognized as liabilities, affecting the costs and expenses relating to the transactions that gave rise to them.

o. Impuesto Especial sobre Producción y Servicios

(Special Tax on Production and Services, or “IEPS Tax”)

The IEPS Tax charged to customers is a withholding tax on domestic sales of gasoline, diesel and fossil fuels. The applicable quotas depend on, among other factors, the product, producer’s price, freight costs, commissions and the region in which the respective product is sold. The withholding tax does not affect the results of PEMEX.

p. Contingencies

Contingency losses are recorded when it is probable that a liability has been incurred and the amount thereof can be reasonably estimated. When a reasonable estimation cannot be made, qualitative disclosure is provided in the notes to the consolidated financial statements. Contingent revenues, earnings or assets are not recognized until realization is assured.

q. Revenue recognition

Sales revenue is recognized at the moment when the risks and benefits of ownership of crude oil, refined or gas products, and derivative and petrochemical products are transferred to the customers who acquire them, which occurs as follows:

• in accordance with contractual terms;

• the moment at which the customer picks up product at PEMEX’s facilities; or

• the moment at which PEMEX delivers the product to the delivery point.

Services rendered are recognized as services income when the customers accept the receipt of the services.

r. Presentation of consolidated statements of comprehensive income

The costs and expenses shown in PEMEX’s consolidated statements of comprehensive income are presented based on their function, which allows for a better understanding of the components of PEMEX’s operating income. This classification allows for a comparison to the industry to which PEMEX belongs.

Revenues

Represents revenues from sale or products or services.

Cost of sales

Cost of sales represents the acquisition and production costs of inventories at the time of sale. Cost of sales mainly includes depreciation, amortization, salaries, wages and benefits, a portion of the cost of the reserve for employee benefits and operating expenses related to the production process.

Other revenues (expenses), net

Other revenues (expenses), net consist primarily of income and expenses that are not related directly to the operation of PEMEX.

Transportation, distribution and sale expenses

Transportation, distribution and sale expenses are costs in connection with the storage, sale and delivery of products, such as the depreciation and operating expenses associated with these activities.

Administrative expenses

Administrative expenses are costs related to PEMEX’s areas that provide administrative support.

Financing income

Financing income is comprised of interest income, financial income and other income from financial operations between PEMEX and third parties.

Financing cost

Financing cost is comprised of interest expenses, commissions and other expenses related to PEMEX’s financing operations less any portion of the financing cost that is capitalized.

Derivative financial instruments (cost) income, net

Derivative financial instruments (cost) income represents the net effect of the profit or loss for the year associated with DFIs.

Foreign exchange loss, net

Exchange rate variations relating to assets or liabilities governed by contracts denominated in foreign currencies are recorded in income (loss) for the year.

s. Operating segments

Operating segments are identifiable components of PEMEX that pursue business activities from which PEMEX earns revenues and incurs expenses, including those revenues and expenses from transactions with other segments of PEMEX, and for which information is available to management on a segmented basis and is assessed by the Board of Directors in order to allocate resources and assess the profitability of the segments.

t. Non-current assets held for sale, non-current assets held for distribution to owners and discontinued operations

Non-current assets held for sale

PEMEX classifies a non-current asset, or a disposal group of assets, as held for sale if (a) its carrying amount will be recovered principally through a sale transaction rather than through continuing use; (b) the asset or group of assets is available in its present condition for immediate sale and (c) the sale is expected to be completed within one year from the date of classification, or more, with certain exceptions.

Non-current assets classified as held for sale are measured at the lower of its carrying amount, and fair value less cost of sales and presented in a separate line item in the consolidated statements of financial position. Non-current assets classified as held for sale are not subject to depreciation or amortization after the classification as held for sale.

The liabilities of a disposal group classified as held for sale are presented separately from other liabilities in the statement of financial position. Those assets and liabilities are not offset and are presented as a single amount.

Non-current asset held for distribution to owners

When PEMEX agrees to distribute a non-current asset, or a disposal group of assets, to owners, this asset or disposal group of assets, is classified as held for distribution to owners if: a) a non-current asset or disposal group of assets is available for immediate distribution in its present condition and b) the distribution must be highly expected to be completed within one year from the date of classification, with certain exceptions.

Non-current assets classified as held for distribution are measured at the lower of their carrying amount and fair value less cost of distribution and are presented in a separate line item in the consolidated financial statements. Non-current assets classified as held for distribution are not subject to depreciation or amortization after the classification as held for distribution.

The liabilities of a disposal group classified as held for distribution to owners are presented separately from other liabilities in the statement of financial position. Those assets and liabilities shall not be offset and shall be presented as a single amount.

Discontinued operations

A discontinued operation is a component of an entity that either has been disposed of or is classified as held for sale, and either:

• represents a separate major line of business or geographical area of operations;

• is part or a single coordinated plan to dispose of a separated major line of business or geographical area of operations; or

• is a subsidiary acquired exclusively with a view to resale.

The revenues or expenses from discontinued operations, including profits or losses from previous years, are presented in a specific line item in the consolidated statements of comprehensive income.

u. Accounting changes

The IASB issued new amendments to the IFRS mentioned below, which are applicable to PEMEX and are effective for annual periods beginning January 1, 2017:

a) IAS 12 “Income Taxes: Recognition of Deferred Tax Assets for Unrealized Losses” (“IAS 12”)

The IASB issues amendments to IAS 12 to clarify the diversity of practices in the recognition of deferred tax assets for unrealized losses related to debt instruments measured at fair value.

The amendments to IAS 12 include some explanatory paragraphs and an illustrative example.

The amendments clarify the following aspects of IAS 12:

• Unrealized losses on debt instruments measured at fair value for accounting purposes and measured at cost for tax purposes give rise to deductible temporary differences regardless of whether the debt instrument’s holder expects to recover the carrying amount of the debt instrument by sale or by use.

• The carrying amount of an asset does not limit the estimation of probable future taxable profits.

• Estimates of future taxable profits exclude tax deductions resulting from the reversal of deductible temporary differences.

• An entity assesses a deferred tax asset in combination with other deferred tax assets. Where tax law restricts the utilization of tax losses, an entity would assess a deferred tax asset in combination with other deferred tax assets of the same type.

The amendments are to be applied retrospectively and are effective for annual periods beginning on or after January 1, 2017. Earlier application is permitted.

These amendments had no impact on these consolidated financial statements.

b) Amendments to IAS 7 “Statement of Cash Flows” (“IAS 7”)

The IASB issued amendments to IAS 7. The amendments are intended to clarify disclosure provided to the user of financial statements about an entity’s financing activities.

Changes

The amendments in IAS 7 come with the objective that entities shall provide disclosures that enable users of financial statements to evaluate changes in liabilities arising from financing activities.

To achieve this objective, the IASB requires that the following changes in liabilities arising from financing activities are disclosed: (i) changes from financing cash flows; (ii) changes arising from obtaining or losing control of subsidiaries or other businesses; (iii) the effects of changes in foreign exchange rate; (iv) changes in fair values; and (v) other changes.

The IASB defines liabilities arising from financing activities as liabilities “for which cash flows were, or future cash flows will be, classified in the statements of cash flows as cash flows from financing activities.” It also stresses that the new disclosure requirements also relate to changes in financial assets if they meet the same definition.

The amendments state that one way to fulfill the new disclosure requirements is to provide reconciliation between the opening and closing balances in the statement of financial position for liabilities arising from financing activities.

Finally, the amendments state that changes in liabilities arising from financing activities must be disclosed separately from changes in other assets and liabilities.

The amendments are effective for annual periods beginning on or after January 1, 2017. Earlier application is permitted. Entities need not provide comparative information when they first apply the amendments.

Impacts on this amendments are disclosed in Note 15.

c) IFRS 12 “Disclosure of Interest in Other Entities” (“IFRS 12”)—Annual Improvements to IFRS 2014—2016 Cycle.

As of December 2016, the IASB published Annual Improvements to IFRS 2014—2016 Cycle, which clarified the scope of IFRS 12, by specifying that the disclosure requirements apply to all subsidiaries, joint arrangements, associates and unconsolidated structured entities classified as held for sale, held for distribution or as discontinued operations in accordance with IFRS 5, with certain exceptions.

The amendments are going to be applied restrospectively and are effective for annual periods beginning on or after January 1, 2017.

These improvements had no impact on these consolidated financial statements.

v. New IFRS not yet adopted

The IASB issued amendments and new IFRS that are not effective as of December 31, 2017 but that could have an impact on subsequent PEMEX financial statements.

Amendments effective for periods beginning in 2018:

a) IFRS 15, “Revenue from Contracts with Customers” (“IFRS 15”)

The core principle of the new IFRS 15 is that an entity should recognize revenue as the promised transfer of goods or services to the customer, valued at the amount that the entity expects to be entitled in exchanged for those goods or services.

Pursuant to IFRS 15, an entity should:

• identify customer contracts that fall within the scope of the new standard;

• identify the separate performance obligations in the contract based on the following criteria: (i) sales of goods or services, separately, (ii) sales that are dependent or interrelated with other products or services; and (iii) homogeneous and consistent sales pattern;

• determine the price of the transaction by applying the following considerations: (i) variable consideration and constraining estimates of variable consideration; (ii) the existence of a significant financing component in the contract; (iii) any non-cash consideration; and (iv) the consideration payable to the customer;

• allocate the transaction price to each separate performance obligation; and

• recognize revenue when (or as) each performance obligation is satisfied either over time or at a point in time.

The new IFRS 15 enhances disclosures of revenue. This standard must be applied for periods beginning on or after January 1, 2018, and early application is permitted. During the year of application, entities may apply the rule retrospectively or use a modified approach.

PEMEX will adopt IFRS 15 retrospectively with the cumulative effect of applying the new standard recognized at the date of initial adoption (January 1, 2018) as an adjustment to the opening balance of retained earnings or other component of equity, as applicable. Under this transition method, PEMEX elected to apply this standard retrospectively only to contracts that were not completed contracts at January 1, 2018. For contracts that have been completed before December 31, 2017, with revenues not fully recognized as of that date, the current accounting policies under IAS 18 will continue to apply when recognizing revenue of those contracts during 2018. For contracts that take effect from January 1, 2018, revenue will be recognized in accordance with IFRS 15.

As part of the implementation of IFRS 15, different types of revenue from contracts with customers have been identified, evaluated and documented, as well as the main changes in accounting policies that will be reflected as of January 1, 2018 with respect to new contracts. The main changes in accounting policies are as follows:

i. Sale of products with other services:

The adoption of IFRS 15 will affect the manner in which PEMEX records the sale of products including oil, refined products, gas, petrochemicals, fertilizers and other sales. Until December 31, 2017, freight and other services, for example were recognized separately from products sold. Under IFRS 15, revenue is recognized with respect to the performance obligation under the contract, and so certain services that are currently accounted for separately, will now be presented as a single performance obligation together with the sale of the product.

ii. Services:

Services include transportation and storage of hydrocarbons, petroleum, petrochemicals, refined products, gas, petrochemical derivatives and others.

Rental services and some transportation services are currently presented in the revenues from services line item in the income statement. In many cases of services with components of leases are less than one year operating leases. Revenues corresponding to leasing have not been presented separately from revenues from services.

Under IFRS 15, leases cannot be presented in the same line item as revenues from service. The main change in accounting policy will be the separation and presentation of service and lease components.

iii. Determination of the transaction price:

Refunds, discounts, quantity and quality claims (in favor or against) and penalties (to customers or PEMEX) or breaches related to the sale of certain products were previously recognized as revenues. However, under IFRS 15, revenues will only be recognized if it is highly probable that there will not be a significant reversal in the revenue received. As a result, PEMEX will put in place mechanisms to approximate the refunds, discounts, quantity and quality claims and penalties at the time that the control of the product is transferred.

Revenue recognition

Revenues are currently recognized when the risks and benefits of the product are transferred, which occurs when the customer picks up or receives the product at PEMEX´s facilities or at a specific point of sale, accepts the products and assumes the risks and benefits related to the transfer of ownership.

Under IFRS 15, revenues from sale of products are recognized when the contractual obligation is satisfied, and control of the products is transferred to the customer. There will be changes in the revenue recognition of gas sale and certain services from “one point in time” to “over time”. However, a significant change is not expected because in some cases the practical expedient “right to invoice” will be applied to measure progress towards completion of the transaction.

As of December 31, 2017, PEMEX did not identify any significant uncompleted contracts. As a result, PEMEX has determined that the changes to amounts in prior years will not be significant. Nonetheless, there will be important changes in accounting policies for contracts issued as of January 1, 2018.

b) IFRS 9, “Financial Instruments” (“IFRS 9”(2014))

In July 2014, the IASB finalized the accounting reform of financial instruments and issued IFRS 9 (revised in 2014), which contains the requirements for, a) the classification and measurement of financial assets and liabilities, b) impairment methodology, and c) general information about hedge accounting. IFRS 9 (revised in 2014) replaces IAS 39 Financial Instruments: Recognition and Measurement as of its effective date.

These requirements should be applied retrospectively and, as permitted by IFRS 9 transitional provisions, it is not necessary for companies to restate comparative figures. Any adjustment in the carrying amounts of the financial assets and liabilities at the transition date is recognized by affecting the cumulative effect in the initial opening period.

The classification criteria depends on a combination of two important factors:

i. the business model within the financial asses is held (the business model test); and

ii. the contractual cashflow of the financial asset (the SPPI test). Based on these two tests, the asset can be measured as follows:

• Amortized cost: Financial Instruments under a business model whose objective is only the collection of contractual cash flows which are composed of principal and interest payments and where there are no significant sales unjustified and fair value is not a key factor in the management of these financial assets and the characteristics of cash flows represent substantially a “basic loan agreement” or SPPI. Unjustified sales are different from sales related to an increase in the credit risk of an asset or unexpected financing needs.

• Fair value with changes through other comprehensive income (“FVOCI”): Financial Instruments in a business model whose objective is to obtain cash flows and the sale of those assets, where fair value is a key factor in its management. In addition, the characteristics of the contractual cash flows represent substantially a “basic loan agreement”.

• Fair value with changes through profit or loss (“FVPL”): Financial instruments in a business model whose objective is not the aforementioned models, where fair value is a key factor in the management of these assets, and the financial instruments whose contractual cash flow characteristics do not substantially represent a “basic loan agreement”.

IFRS also replaces the impairment model of IAS 39 (the “loss incurred model”) with a new impairment model called the “expected credit loss” model. This impairment model will be applicable to financial assets that are not measured at FVPL. Changes in fair value of financial assets through FVOCI to the point of disposal are recorded in OCI.

The expected credit loss recognized for impairment purposes under IFRS 9 will be equivalent to a 12-month reserve, except when the financial instrument presents a “significant increase in credit risk” or presents objective evidence of impairment, recognizing a reserve equivalent to the remaining life of the financial instrument, based on the definition of general approach under IFRS 9.

IFRS 9 Implementation and government strategy

PEMEX has established a multidisciplinary working group with the objective to adapt its processes to the new standard in relation to the classification and measurement of financial instruments and the impairment estimation of credit risk, ensuring that these processes have been applied and adopted in accordance with IFRS 9.

Regarding classification and measurement, PEMEX carried out an analysis of its financial assets in order to identify those that could trigger a change in the accounting methodology, due to the definition of the business model and a failure to satisfy the SPPI test.

IFRS 9 Implementation analysis

PEMEX has defined January 1, 2018 as the initial date of adoption of IFRS 9 “Financial Instruments” and according to the transitional standard in IFRS 9, PEMEX will not restate previous periods for comparison purposes and any difference that may arise as a result of the adoption of IFRS 9 between the previous carrying amount and the carrying amount at the beginning of the reporting period shall be recognized in accumulated results over the opening initial period.

PEMEX has concluded that most of its financial assets will continue to be classified in the same way:

	Classification
Assets	IAS 39	IFRS 9	Change
Cash and cash equivalents	FVPL	FVPL		No
Available—for—sale financial assets	FVOCI	FVOCI		No
Derivative financial instruments	FVPL	FVPL		No
Long—term notes receivable	Amortized Cost	Amortized Cost		No

Capital or debt instruments classified as available-for-sale financial assets will continue to be measured at FVOCI.

PEMEX has concluded that the financial assets most affected by the impairment estimate under the expected credit loss model will be its accounts receivables, in relation to PEMEX’s holding of the long-term notes issued by the Mexican Government. The evaluation of the possible impairment of the notes will be made using the general approach for calculating impairment of the notes will be made using the general approach for calculating impairment contemplated under IFRS 9.

PEMEX considers it probable that impairment losses increase and present more volatility for instruments under the new methodology of expected credit losses. Furthermore, PEMEX considers that most of its accounts receivable are short-term without a significant financial component, so the simplified approach will be applied.

The preliminary evaluation of PEMEX indicates that the application of the new impairment requirements of IFRS 9 as of December 31, 2017 will impact the accounts receivable reserves as of January 1, 2018. An increase between 39.0% and 51.1% is expected in the accounts receivable reserves as compared to impairment losses incurred in accordance with IAS 39.

Hedge accounting

PEMEX, as part of the initial adoption, elected to continue applying the hedge accounting requirements of IAS 39 instead of IFRS 9. PEMEX uses DFI’s to cover the exposure of foreign currency risk, interest rate risk and fluctuations in the price of its products, but these contracts are not accounted for as designated hedges. DFI’s are initially recognized at fair value on the date the derivative contract is entered into and after initial recognition are measured again at fair value.

As a result, PEMEX has determined that the changes to amounts in prior years will not be significant.

c) Interpretation of IFRIC 22 “Foreign Currency Transactions and Advance Considerations” (IFRIC 22)

As of December 2016, IASB published an interpretation of IFRIC 22 developed by the International Financial Reporting Standards Interpretations Committee (the Interpretations Committee). The interpretation clarified when to recognize payments and collections of foreign currency transactions paid in advance.

According to the interpretations, an entity must recognize foreign currency transactions when:

i. there is consideration that is denominated or priced in a foreign currency;

ii. the entity recognizes a prepayment asset or a deferred income liability in respect of that consideration, in advance of the recognition of the related asset, expense or income; and

iii. the prepayment asset or deferred income liability is non-monetary.

The Interpretations Committee concluded that:

• The date of the transaction, for the purpose of determining the exchange rate, is the date of initial recognition of the non- monetary prepayment asset or deferred income liability.

• If there are multiple payments or receipts in advance, a date of transaction is established for each payment or receipt.

IFRIC 22 is effective for annual reporting periods beginning on or after January 1, 2018. Entities may apply the rule retrospectively, or prospectively, in accordance with IAS 8 with certain exemptions.

PEMEX believes that these standards will not have an impact on its consolidated financial statements.

Standards effective for periods beginning in 2019

a) IFRS 16, “Leases” (“IFRS 16”)

In January 2016, the IASB published a new accounting standard IFRS 16, which replaces IAS 17, “Leases and Guide interpretations.”

The main changes from the previous standard are:

• IFRS 16 provides a comprehensive model for the identification of the lease arrangements and their treatment in the financial statements of both lessees and lessors;

• the new standard applies a control model to the identification of leases, distinguishing between leases and service contracts on the basis of whether there is an identified asset controlled by the customer;

• the distinction between financial and operating leasing is removed, therefore, the assets and liabilities are recognized in respect of all leases, with some exceptions for short-term leases and leases of low-value assets; and

• the standard does not include significant changes to the requirements for accounting by lessors.

The standard is effective for annual periods beginning on or after January 1, 2019, with earlier application permitted for entities that have also adopted IFRS 15, “Revenue from Contracts with Customers.”

PEMEX has established a multidisciplinary working group with the objective to adapt its processes to the new standard in the following phases: (i) training, (ii) obtaining information, (iii) diagnostic, (iv) determination of initial adjustments and (v) integration of change. As of the date of these consolidated financial statements, the training phase for the accounting staff is complete and PEMEX is in the process of analyzing leasing contracts in order to determine necessary changes to its procedures and reports. PEMEX has not determined the impact of IFRS 16 on its net income (loss) for the year. PEMEX estimates that it will conclude the implementation of IFRS 16 in February 2019.

b) Annual improvements—2015-2017 Cycle

In December 2017, the IASB published “the Annual Improvements to the IFRS of the 2015-2017 Cycle” through which it clarifies the following IFRS:

• IFRS 3 Business Combinations and IFRS 11 Joint Arrangements

IFRS 3 Business Combinations clarifies how an entity should recognize an increase of its interest in a joint operation:

• When a party to a joint arrangement obtains control of a business that was a part of that joint arrangement, and where that party had assumed a portion of the rights to the assets and obligations to the liabilities of that business prior to the acquisition date, the acquisition will be considered a business combination that is achieved in stages. The acquiriting entity must therefore apply the requirements for a business combination achieved in stages, including by measuring its previously held interest in the joint arrangement.

• When a party participates in, but does not share in the control of a joint operation, and subsequently takes joint control of that joint operation, this will constitute the acquisition of a business and previously held interest in the joint operation are not measured.

• IAS 12 Income Tax

All income tax consequence of dividends (including payments on financial instruments classified as equity) are recognized consistently with the transactions that generated the distributable profits (i. e. in profit or loss, other comprehensive income or equity basis).

• IAS 23 Borrowing Costs

With respect to the treatment of costs for loans subject to capitalization, the amendments clarify that:

• To the extent that an entity borrows funds generally and uses them for the purpose of obtaining a qualifying asset, that entity shall determine the amount of borrowing costs eligible for capitalization by applying a capitalization rate to the expenditures on that asset. The capitalization rate shall be the weighted average of the borrowing costs applicable to all borrowings of the entity that are outstanding during the period.

• However, an entity shall exclude from this calculation borrowing cost applicable to borrowing made specifically for the purpose of obtaining a qualifying asset until substantially all the activities necessary to prepare that asset for its intended used or sale are complete.

The amount of borrowing costs that an entity capitalizes during a period shall not exceed the amount of borrowing costs it incurred during that period.

The amendments are effective for annual periods beginning on or after January 1, 2019.

PEMEX is in the process of evaluating the impact that these amendments will have on its consolidated financial statements.

c) IFRIC 23—Uncertainty over Income Tax Treatments

In June 2017, the IASB published a new accounting interpretation to be applied to the determination of taxable profit (tax loss), tax bases, unused tax losses, unused tax credits and tax rates, where there is uncertainty over income tax treatments under IAS 12.

In order to make these tax assessments, an entity must consider whether it is probable that the relevant taxing authority will accept each tax treatment, or group of tax treatments, that the entity has used or plans to use in its next income tax filing:

• If the entity concludes that it is probable that a particular tax treatment will be accepted by the relevant taxing authority, that entity must determine taxable profit (tax loss), tax bases, unused tax losses, unused tax credits or tax rates consistently with the tax treatment included in its income tax filings.

• If the entity concludes that it is not probable that a particular tax treatment is accepted by the relevant taxing authority, the entity must use the most likely amount or the expected value of the tax treatment when determining taxable profit (tax loss), tax bases, unused tax losses, unused tax credits and tax rates. That calculation should be based on which method provides better predictions of the resolution of the uncertainty.

IFRIC 23 is effective for annual reporting periods beginning on or after January 1, 2019. Earlier application is permitted. PEMEX does not anticipate being impacted by IFRIC 23 because all tax positions are discussed and agreed with the SHCP prior to releasing quarterly or annual financial statements.

w. Reclassifications

Due to a significant loss of control over TAG Norte Holdings, S. de R.L. de C.V. and TAG Pipelines Sur, S. de R.L. de C.V., whose investment in these companies was presented in investments in joint ventures and associates in the past was reclassified to available-for-sale financial assets as of December 31, 2017. Accordingly the balance as of these investments as of December 31, 2016 was reclassified for purposes of improving its presentation the consolidated statements of financial position as follows:

	2016
Line item	As previously (reported)		Reclassification			Following reclassification
Available—for—sale financial assets		Ps.          435,556		Ps. 2,417,123			Ps.       2,852,679
Total current assets		355,398,800		2,417,123			357,815,923
Investments in joint ventures and associates		23,154,632		(2,417,123	)		20,737,509
Total non-current assets		1,974,487,224		(2,417,123	)		1,972,070,101

These reclassifications had no impact on PEMEX’s total assets.

Due to the fact that reinsurance premiums from KOT Insurance Company, AG., from which PEMEX derives revenue, are not part of the core services provided by PEMEX, they are included in other income (expenses), net. Therefore, for comparison purposes, the consolidated statements of comprehensive income for the years ended December 31, 2016 and 2015 were reclassified as follow:

	2016
Line item	As previously (reported)		Reclassification			Following reclassification
Services income		Ps.     14,427,081		Ps. (5,452,439	)		Ps.       8,974,642
Total of sales		1,079,545,671		(5,452,439	)		1,074,093,232
Cost of sales		867,580,634		(1,758,413	)		865,822,221
Gross income (loss)		543,279,380		(3,694,026	)		539,585,354
Other income (expenses), net		18,955,580		3,694,026			22,649,606

	2015
Line item	As previously (reported)			Reclassification			Following reclassification
Services income		Ps.     12,912,112			Ps. (4,602,077	)		Ps.       8,310,035
Total of sales		1,166,362,469			(4,602,077	)		1,161,760,392
Cost of sales		895,068,904			(3,104,298	)		891,964,606
Gross income (loss)		(114,474,036	)		(1,497,779	)		(115,971,815	)
Other income (expenses), net		(2,373,266	)		1,497,779			(875,487	)

These reclassifications had no impact on PEMEX’s net income.

In order to provide a better presentation in Duties, taxes and other, certain amounts in Income Tax line item, were reclassified to Hydrocarbon extraction duties and others line item, as follows:

	2016
Line item	As previously (reported)			Reclassification			Following reclassification
Hydrocarbon extraction duties and others		Ps.  304,813,375			Ps.  (27,651,571	)		Ps.  277,161,804
Income tax		(40,291,940	)		27,651,571			(12,640,369	)

These reclassifications had no impact on PEMEX’s net income.

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Subsidiary Entities and Subsidiary Companies

12 Months Ended

Dec. 31, 2017

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Subsidiary Entities and Subsidiary Companies

NOTE 4. SUBSIDIARY ENTITIES AND SUBSIDIARY COMPANIES

As of December 31, 2017, the Subsidiary Entities consolidated in these financial statements include Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Cogeneration and Services, Pemex Drilling and Services, Pemex Logistics, Pemex Fertilizers and Pemex Ethylene.

The consolidated Subsidiary Companies are as follows:

• P.M.I. Marine, DAC. (PMI Mar) ⁽ⁱ⁾

• P.M.I. Services, B.V. (PMI SHO) ⁽ⁱ⁾

• P.M.I. Holdings, B.V. (PMI HBV) ^(i)(x)

• P.M.I. Trading, Ltd. (PMI Trading) ⁽ⁱ⁾

• PEMEX Internacional España, S. A. (PMI SES) ^(i)(viii)

• P.M.I. Holdings Petróleos España, S. L. (HPE) ⁽ⁱ⁾

• P.M.I. Services North America, Inc. (PMI SUS) ⁽ⁱ⁾

• P.M.I. Holdings North America, Inc. (PMI HNA) ^(i)(ix)

• P.M.I. Norteamérica, S. A. de C. V. (PMI NASA) ⁽ⁱ⁾

• P.M.I. Comercio Internacional, S. A. de C. V. (PMI CIM) ^(i)(ii)

• PMI Field Management Resources, S. L. (FMR) ^(i)(xi)

• PMI Campos Maduros SANMA, S. de R. L. de C. V. (SANMA) ⁽ⁱ⁾

• Pro-Agroindustria, S. A. de C. V. (AGRO)

• PMI Azufre Industrial, S. A. de C. V. (PMI AZIND) ⁽ⁱ⁾

• PMI Infraestructura de Desarrollo, S. A. de C. V. (PMI ID) ⁽ⁱ⁾

• PMI Cinturón Transoceánico Gas Natural, S. A. de C. V. (PMI CT) ⁽ⁱ⁾

• PMI Transoceánico Gas LP, S. A. de C. V. (PMI TG) ⁽ⁱ⁾

• PMI Servicios Portuarios Transoceánicos, S. A. de C. V. (PMI SP)

• PMI Midstream del Centro, S. A. de C. V. (PMI MC) ⁽ⁱ⁾

• PEMEX Procurement International, Inc. (PPI)

• Hijos de J. Barreras, S. A. (HJ BARRERAS) ⁽ⁱⁱ⁾

• PEMEX Finance, Ltd. (FIN) ⁽ⁱⁱ⁾

• Mex Gas Internacional, S. L. (MGAS)

• Pemex Desarrollo e Inversión Inmobiliaria, S. A. de C. V. (PDII)

• Kot Insurance Company, AG. (KOT)

• PPQ Cadena Productiva, S.L. (PPQCP)

• III Servicios, S. A. de C. V. (III Servicios)

• PMI Ducto de Juárez, S. de R.L. de C.V. (PMI DJ)^(i)(iii)

• PMX Cogeneración Internacional, S.L. (MG COG) ^{(iv)(vi)(xii)}

• PMX Cogeneración S.A.P.I. de C.V. (PMX COG)^{(iv) (xii)}

• PMX Fertilizantes Holding, S.A de C.V. (PMX FH) ^(iv)

• PMX Fertilizantes Pacífico, S.A. de C.V. (PMX FP) ^(iv)

• Grupo Fertinal (GP FER) ^(iv)

• Compañía Mexicana de Exploraciones, S.A. de C.V. (COMESA)^(v)

• P.M.I Trading Mexico, S.A. de C.V. (TRDMX) ^(vii)

• Holdings Holanda Services, B.V. (HHS) ^(x)

i. Member Company of the “PMI Subsidiaries”.

ii. Non-controlling Interest Company.

iii. As of January 2016, this company started operations and was included in the consolidated financial statements of PEMEX.

iv. As of June 2016, this company was included in the consolidated financial statements of PEMEX.

v. As of July 2016, this company was included in the consolidated financial statements of PEMEX.

vi. Until October 2016, formerly Mex Gas Cogeneración S.L.

vii. As of January 2017, this company started operations and was included in the consolidated financial statements of PEMEX

viii. As of February 2017, this company merged with HPE.

ix. As of June 2017, this company merged with SUS.

x. As of October 2017, PMI HBV was divided and HHS was created and included in the consolidated financial statements of PEMEX.

xi. This Company was liquidated.

xii. As of December 2017, PEMEX acquired shares in these companies and they were included in the consolidated financial statements of PEMEX.

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Segment financial information

12 Months Ended

Dec. 31, 2017

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Segment financial information

NOTE 5. Segment financial information

PEMEX’s primary business is the exploration and production of crude oil and natural gas, as well as the production, processing, marketing and distribution of petroleum and petrochemical products. After the Corporate Reorganization, PEMEX’s operations have been conducted through nine business segments: exploration and production, industrial transformation, cogeneration and services, drilling and services, logistics, ethylene, fertilizers, the Trading Companies and corporate and other operating subsidiary companies. Due to PEMEX’s structure, there are significant quantities of inter-segment sales among the reporting segments, which are made at internal transfer prices established by PEMEX reflecting international market prices.

The primary sources of revenue for PEMEX’s business segments are as described below:

• The exploration and production segment earns revenues from domestic sales of crude oil and natural gas, and from exporting crude oil through certain of the Trading Companies. Export sales are made through PMI CIM to approximately 32 major customers in various foreign markets. Approximately half of PEMEX’s crude oil is sold to Pemex Industrial Transformation.

• The industrial transformation segment earns revenues from sales of refined petroleum products and derivatives, mainly to third parties within the domestic market. This segment also sells a significant portion of the fuel oil it produces to the Comisión Federal de Electricidad (Federal Electricity Commission, or “CFE”) and a significant portion of jet fuel produced to Aeropuertos y Servicios Auxiliares (the Airports and Auxiliary Services Agency). The refining segment’s most important products are different types of gasoline and diesel.

• The industrial transformation segment also earns revenues from domestic sources generated by sales of natural gas, liquefied petroleum gas, naphtha, butane and ethane and certain other petrochemicals such as methane derivatives, ethane derivatives, aromatics and derivatives.

• The cogeneration segment receives income from the cogeneration, supply and sale of electricity and thermal energy and also provides technical and management activities associated with these services.

• The drilling segment receives income from drilling services, and servicing and repairing wells.

• The logistics segment earns income from transportation and storage of crude oil, petroleum products and petrochemicals, as well as related services, which it provides by employing pipelines and offshore and onshore resources, and from providing services related to the maintenance, handling, guarding and management of these products.

• The ethylene segment earns revenues from the distribution and trade of methane, ethane and propylene in the domestic market.

• The fertilizers segment earns revenues from trading ammonia, fertilizers and its derivatives, mostly in the domestic market.

• The trading companies segment, which consist of PMI CIM, PMI NASA, PMI Trading and MGAS (the “Trading Companies”), earn revenues from trading crude oil, natural gas and petroleum and petrochemical products in international markets.

• The segment related to corporate and other operating Subsidiary Companies provides administrative, financing, consulting and logistical services, as well as economic, tax and legal advice and re-insurance services to PEMEX’s entities and companies.

The following tables present the condensed financial information of these segments, after elimination of unrealized intersegment gain (loss), and include only select line items. As a result, the line items presented below may not total. These reporting segments are those which PEMEX’s management evaluates in its analysis of PEMEX and on which it bases its decision-making.

As of/for the year ended December 31, 2017	Exploration and Production			Industrial Transformation			Cogeneration and Services(1)			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies			Intersegment eliminations			Total
Sales:
Trade	Ps.	—			Ps. 857,456,146		Ps.	—		Ps.	—		Ps.	—			Ps. 4,123,006			Ps. 12,621,648			Ps. 508,539,112			Ps. 3,159,238		Ps.	—			Ps. 1,385,899,150
Intersegment		762,637,362			150,360,283			114,233			3,400,456			70,671,871			642,965			1,565,757			539,193,190			79,031,944			(1,607,618,061	)		—
Services income		—			6,116,937			334,755			41,741			3,714,941			2,339			26,733			66,621			826,502			—			11,130,569
(Reversal) impairment of wells pipelines, properties, plant and equipment, net		129,350,315			15,952,092			—			—			—			1,935,500			—			—			4,206,653			—			151,444,560
Cost of sales		391,089,410			1,004,683,554			472,732			468,171			50,926,263			6,001,259			14,272,340			1,031,997,901			33,033,923			(1,528,740,673	)		1,004,204,880
Gross income (loss)		242,197,637			(6,702,280	)		(23,744	)		2,974,026			23,460,549			(3,168,449	)		(58,202	)		15,801,022			45,777,108			(78,877,388	)		241,380,279
Other revenues (expenses), net		10,204,045			1,515,538			2,646			(31,454	)		(24,134,436	)		9,013			23,030			307,212			(5,344,872	)		22,623,354			5,174,076
Distribution, transportation and sales expenses		—			26,049,566			13,581			—			73,526			528,370			334,663			375,482			59,043			(5,544,561	)		21,889,670
Administrative expenses		58,539,119			38,994,887			37,679			888,776			7,459,928			352,537			1,105,554			1,564,859			62,001,641			(51,005,526	)		119,939,454
Operating income (loss)		193,862,563			(70,231,195	)		(72,358	)		2,053,796			(8,207,341	)		(4,040,343	)		(1,475,389	)		14,167,893			(21,628,448	)		296,053			104,725,231
Financing income		121,293,404			11,427,907			147			57,313			1,622,827			2,248			46,113			905,405			145,907,795			(265,097,306	)		16,165,853
Financing cost		(136,378,338	)		(2,398,643	)		(19,882	)		(795,947	)		(2,307,427	)		(211,004	)		(1,964	)		(1,328,827	)		(239,003,771	)		264,801,255			(117,644,548	)
Derivative financial instruments (cost) income, net		(1,613,874	)		5,835			—			—			—			—			—			(772,143	)		27,718,506			—			25,338,324
Foreign exchange (loss) income, net		10,043,316			4,924,209			—			227,365			613,099			(20,925	)		(10,486	)		(4,318	)		7,411,862			—			23,184,122
Profit (loss) sharing in joint ventures and associates		(75,195	)		485,224			—			—			(74	)		—			—			1,049,809			(212,666,494	)		211,567,170			360,440
Taxes, duties and other		338,169,260			—			—			276,967			(7,444,967	)		—			—			1,972,718			6,063			—			332,980,041
Net (loss) income		(151,037,384	)		(55,786,663	)		(92,093	)		1,265,560			(833,949	)		(4,270,024	)		(1,441,726	)		12,045,101			(292,266,613	)		211,567,172			(280,850,619	)
Total current assets		1,036,063,541			570,380,888			179,807			6,871,148			49,391,784			3,155,476			3,994,381			158,414,445			506,187,594			(1,971,112,774	)		363,526,290
Investments in joint ventures and associates		64,328			4			—			—			18,336			—			—			15,805,506			(465,026,224	)		465,845,414			16,707,364
Wells, pipelines, properties, plant and equipment, net		945,945,889			286,423,735			—			18,956,882			119,647,553			5,713,998			19,008,822			6,739,231			34,073,216			—			1,436,509,326
Total assets		2,058,036,405			857,196,306			179,807			26,220,748			191,895,993			8,923,456			23,142,045			186,808,899			2,111,740,735			(3,332,142,280	)		2,132,002,114
Total current liabilities		284,656,058			459,130,165			531,580			2,201,936			44,521,371			6,455,246			2,183,654			112,046,527			1,439,097,882			(1,961,697,234	)		389,127,185
Long-term debt		1,826,843,268			25,437,147			—			11,258,734			2,814,640			—			—			2,712,654			1,837,690,559			(1,826,091,398	)		1,880,665,604
Employee benefits		372,032,958			588,573,518			—			333,212			1,842,892			98,361			105,033			(966,238	)		296,416,386			—			1,258,436,122
Total liabilities		2,570,412,398			1,077,108,748			531,580			13,886,424			56,706,251			6,556,050			2,308,890			116,842,881			3,587,988,972			(3,797,987,695	)		3,634,354,499
Equity (deficit), net		(512,375,993	)		(219,912,442	)		(351,773	)		12,334,324			135,189,742			2,367,406			20,833,155			69,966,018			(1,476,248,237	)		465,845,415			(1,502,352,385	)
Depreciation and amortization		127,742,568			17,935,112			—			2,368,123			4,562,140			422,930			1,688,493			(19,798	)		2,004,945			—			156,704,513
Net periodic cost of employee benefits		32,794,386			52,538,989			—			39,697			(4,954	)		(1,999	)		(12,561	)		16,166			22,703,351			—			108,073,075
Acquisition of wells, pipelines, properties, plant and equipment		67,845,989			14,678,182			—			418,283			5,189,409			219,152			475,196			321,145			4,832,461			—			93,979,817

(1) Certain of the assets of Pemex Cogeneration and Services have been transferred to Pemex Industrial Transformation.

As of/for the year ended December 31, 2016	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies			Intersegment eliminations			Total
Sales:
Trade	Ps.	—		Ps.	648,088,013		Ps.	—		Ps.	—		Ps.	—		Ps.	3,873,403		Ps.	15,392,552		Ps.	395,118,117		Ps.	2,646,505		Ps.	—		Ps.	1,065,118,590
Intersegment		616,380,615			117,096,378			51,913			1,981,754			68,316,958			900,464			1,764,438			405,293,283			50,683,175			(1,262,468,978	)		—
Services income		—			5,565,604			132,521			70,112			2,813,887			1,908			60,141			236,230			473,415			(379,176	)		8,974,642
(Reversal) impairment of wells pipelines, properties, plant and equipment, net		(271,709,433	)		(52,498,881	)		—			—			(5,829,520	)		—			(1,276,509	)		—			—			—			(331,314,343	)
Cost of sales		359,064,884			823,763,927			166,721			143,956			61,248,584			5,506,198			13,936,213			783,691,245			7,260,043			(1,188,959,550	)		865,822,221
Gross income (loss)		529,025,164			(515,051	)		17,713			1,907,910			15,711,781			(730,423	)		4,557,427			16,956,385			46,543,052			(73,888,604	)		539,585,354
Other revenues (expenses), net		27,346,794			19,964,654			—			591,704			(27,189,969	)		32,710			63,989			3,412,711			(906,183	)		(666,804	)		22,649,606
Distribution, transportation and sales expenses		—			50,792,317			8,232			6			148,215			185,168			481,727			229,432			49,162			(26,663,019	)		25,231,240
Administrative expenses		54,509,047			34,183,846			32,126			983,560			7,175,451			731,479			2,101,834			1,157,182			60,497,232			(48,718,224	)		112,653,533
Operating income (loss)		501,862,911			(65,526,560	)		(22,645	)		1,516,048			(18,801,854	)		(1,614,360	)		2,037,855			18,982,482			(14,909,525	)		825,835			424,350,187
Financing income		56,040,129			11,056,345			—			72,995			373,301			4,358			64,582			1,098,079			125,964,466			(180,925,000	)		13,749,255
Financing cost		(109,946,363	)		(3,188,892	)		(12,055	)		(642,711	)		(481,741	)		(20,217	)		(2,980	)		(1,342,351	)		(163,400,779	)		180,193,625			(98,844,464	)
Derivative financial instruments (cost) income, net		—			3,172			—			—			—			—			—			(1,951,959	)		(12,052,200	)		—			(14,000,987	)
Foreign exchange (loss) income, net		(217,166,718	)		(12,858,875	)		—			(1,570,317	)		(1,118,537	)		(29,263	)		(2,843	)		174,866			(21,441,056	)		—			(254,012,743	)
Profit (loss) sharing in joint ventures and associates		(21,164	)		649,520			—			—			—			—			—			1,586,503			(117,426,818	)		117,347,804			2,135,845
Taxes, duties and other		276,647,448			—			—			(481,581	)		(10,010,686	)		—			—			7,380,870			(9,014,616	)		—			264,521,435
Net (loss) income		(45,878,653	)		(69,865,290	)		(34,700	)		(142,404	)		(10,018,145	)		(1,659,482	)		2,096,614			11,166,750			(194,251,296	)		117,442,264			(191,144,342	)
Total current assets		983,260,710			795,237,287			388,422			6,032,213			22,087,801			1,724,967			5,817,262			125,081,531			613,881,578			(2,195,695,848	)		357,815,923
Investments in joint ventures and associates		139,523			257,159			—			—			—			—			—			17,568,893			(247,349,711	)		250,121,645			20,737,509
Wells, pipelines, properties, plant and equipment, net		1,176,504,263			311,432,174			—			21,023,629			86,695,514			7,771,634			20,086,650			6,691,813			37,536,571			—			1,667,742,248
Total assets		2,206,418,541			1,107,094,580			388,423			27,673,598			130,824,921			9,556,469			26,007,319			155,376,864			2,359,024,145			(3,692,478,836	)		2,329,886,024
Total current liabilities		340,011,451			666,467,674			472,236			3,894,121			19,824,792			2,995,088			3,879,828			78,894,485			1,497,612,971			(2,187,862,760	)		426,189,886
Long-term debt		1,737,109,328			31,495,027			—			12,489,423			4,382,109			—			—			3,597,938			1,757,315,685			(1,739,384,968	)		1,807,004,542
Employee benefits		362,312,386			575,277,374			191,876			441,127			571,702			20,362			21,893			(749,034	)		282,321,750			—			1,220,409,436
Total liabilities		2,533,221,665			1,278,138,290			664,829			16,853,202			29,336,417			3,015,450			3,901,722			86,885,889			3,553,477,189			(3,942,600,482	)		3,562,894,171
Equity (deficit), net		(326,803,124	)		(171,043,710	)		(276,406	)		10,820,396			101,488,504			6,541,019			22,105,597			68,490,975			(1,194,453,044	)		250,121,646			(1,233,008,147	)
Depreciation and amortization		124,329,921			17,425,472			—			2,559,357			2,230,557			481,241			1,395,232			86,707			1,931,004			—			150,439,491
Net periodic cost of employee benefits		32,617,215			52,886,397			5,860			31,491			30,340			(1,178	)		1,424			(552,735	)		24,719,602			—			109,738,416
Acquisition of wells, pipelines, properties, plant and equipment		70,418,370			32,254,531			—			2,053,139			26,344,495			889,420			1,724,690			1,019,484			21,031,214			—			155,735,343

As of/for the year ended December 31, 2015	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies			Intersegment eliminations			Total
Sales:
Trade	Ps.	—		Ps.	740,190,020		Ps.	—		Ps.	—		Ps.	—		Ps.	1,494,478		Ps.	4,551,413		Ps.	407,214,446		Ps.	—		Ps.	—		Ps.	1,153,450,357
Intersegment		690,642,133			126,294,195			—			1,511,970			598,853			209,970			473,990			353,137,149			18,296,515			(1,191,164,775	)		—
Services income		—			7,549,061			—			—			10,355,988			236			17,893			661,683			505,032			(10,779,858	)		8,310,035
Impairment of wells, pipelines, properties, plant and equipment		394,396,580			76,442,079			—			—			5,829,519			—			1,276,512			—			—			—			477,944,690
Benefit from change in pension plan		(46,368,308	)		(45,808,781	)		—			—			—			—			—			—			—			—			(92,177,089	)
Cost of sales		427,158,621			876,531,944			2,793			706,896			10,727,462			1,707,548			4,965,414			749,655,199			2,791,350			(1,182,282,621	)		891,964,606
Gross income (loss)		(84,544,760	)		(33,131,966	)		(2,793	)		805,074			(5,602,140	)		(2,864	)		(1,198,630	)		11,358,079			16,010,197			(19,662,012	)		(115,971,815	)
Other revenues (expenses), net		(7,957,202	)		1,243,040			—			38			26,941			14,680			19,909			1,666,783			2,219,539			1,890,785			(875,487	)
Distribution, transportation and sales expenses		—			35,292,527			1,448			—			3,009			4,416			62,071			428,613			254			(6,863,699	)		28,928,639
Administrative expenses		18,454,281			40,529,587			47,670			8,553			104,794			152,404			519,351			1,967,581			61,609,813			(10,921,939	)		112,472,095
Benefit from change in pension plan		(17,853,725	)		(39,975,450	)		—			—			—			—			—			—			(46,031,780	)		—			(103,860,955	)
Operating income (loss)		(93,102,518	)		(67,735,590	)		(51,911	)		796,559			(5,683,002	)		(145,004	)		(1,760,143	)		10,628,668			2,651,449			14,411			(154,387,081	)
Financing income		25,852,078			2,789,535			—			43,690			37			3,503			7,728			1,147,870			110,816,691			(125,670,273	)		14,990,859
Financing cost		(90,822,360	)		(13,738,104	)		2,110			(95,280	)		(61,153	)		—			—			(1,299,580	)		(87,289,616	)		125,530,390			(67,773,593	)
Derivative financial instruments (cost) income, net		—			6,463			—			—			—			—			—			1,347,323			(22,803,663	)		—			(21,449,877	)
Foreign exchange (loss), net		(132,165,427	)		(7,364,486	)		(7,509	)		(92,046	)		(11,090	)		(3,600	)		(2,802	)		(49,190	)		(15,069,424	)		—			(154,765,574	)
(Loss) profit sharing in joint ventures and associates		(473,082	)		671,868			—			—			—			—			—			2,056,259			(749,900,890	)		749,963,960			2,318,115
Taxes, duties and other		376,682,705			1,839,021			—			197,491			(2,069,848	)		—			—			5,134,176			(50,283,298	)		—			331,500,247
Net (loss) income		(667,394,014	)		(87,209,335	)		(57,310	)		455,432			(3,685,360	)		(145,101	)		(1,755,217	)		8,697,174			(711,312,155	)		749,838,488			(712,567,398	)
Total current assets		709,252,019			313,801,630			655,239			2,171,717			49,162,929			1,594,643			4,988,511			73,116,155			275,582,816			(1,163,125,162	)		267,200,497
Investments in joint ventures and associates		919,654			6,687,977			—			—			—			8,500			—			11,845,489			(242,233,405	)		246,937,384			24,165,599
Wells, pipelines, properties, plant and equipment, net		966,144,619			246,463,069			—			22,647,454			58,078,603			7,405,969			18,480,684			3,045,704			22,217,529			—			1,344,483,631
Total assets		1,698,909,240			567,486,579			655,240			24,917,981			111,307,038			9,034,376			23,705,118			93,266,620			1,443,189,885			(2,196,817,877	)		1,775,654,200
Total current liabilities		278,507,394			104,569,842			469,524			1,981,652			14,698,159			1,486,468			4,534,980			34,749,438			1,157,183,570			(1,154,773,306	)		443,407,721
Long-term debt		1,252,239,594			16,707,005			—			12,031,849			4,850,905			—			—			3,607,840			1,285,676,066			(1,274,240,092	)		1,300,873,167
Employee benefits		379,150,943			609,492,623			61,171			417,817			368,036			12,533			3,611			(59,581	)		289,938,288			—			1,279,385,441
Total liabilities		1,985,557,185			735,280,560			530,696			14,431,318			19,917,100			1,499,001			4,538,591			41,420,792			2,747,910,113			(2,443,755,258	)		3,107,330,098
Equity (deficit), net		(286,647,945	)		(167,793,981	)		124,544			10,486,663			91,389,938			7,535,375			19,166,527			51,845,828			(1,304,720,228	)		246,937,381			(1,331,675,898	)
Depreciation and amortization		144,567,149			20,916,796			—			612,741			337,364			158,505			442,504			84,493			831,698			—			167,951,250
Net periodic cost of employee benefits		23,608,485			21,392,600			(298	)		—			(310	)		—			—			(119,819	)		17,668,484			—			62,549,142
Acquisition of wells, pipelines, properties, plant and equipment		184,786,051			68,935,841			—			—			1,544,224			320,762			1,882,108			677,314			6,711,511			—			264,857,811

PEMEX’s management measures the performance of the segments based on operating income and net segment income before elimination of unrealized intersegment gain (loss), as well as by analyzing the impact of the results of each segment on the consolidated financial statements. For certain of the items in these consolidated financial statements to conform with the individual financial statements of the operating segments, they must be reconciled. The tables below present the financial information of PEMEX’s operating segments, before intersegment eliminations:

The following tables present accounting reconciliations between individual and consolidated information.

As of/for the year ended December 31, 2017	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies
Sales:
By segment		Ps.   762,637,362			1,015,157,118			448,988			6,679,132			74,386,812			4,795,196			14,214,138			1,047,874,453			83,017,684
Less unrealized intersegment sales		—			(1,223,752	)		—			(3,236,935	)		—			(26,886	)		—			(75,530	)		—
Total consolidated sales		Ps.   762,637,362			1,013,933,366			448,988			3,442,197			74,386,812			4,768,310			14,214,138			1,047,798,923			83,017,684
Operating income (loss):
By segment		Ps.   194,814,292			(59,989,652	)		(72,358	)		882,692			(61,696,313	)		(7,148,431	)		(4,698,838	)		14,490,017			(21,628,448	)
Less unrealized intersegment sales		—			(1,223,752	)		—			(3,236,935	)		—			(26,886	)		—			(75,530	)		—
Less unrealized gain due to production cost valuation of inventory		(496,329	)		(9,017,791	)		—			2,932,663			—			—			—			(246,594	)		—
Less capitalized refined products		(574,381	)		—			—			—			—			—			—			—			—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			—			—
Less depreciation and impairment of revaluated transferred assets		—			—			—			1,475,376			53,488,972			3,134,974			3,223,449			—			—
Total consolidated operating income (loss)		Ps.   193,862,563			(70,231,195	)		(72,358	)		2,053,796			(8,207,341	)		(4,040,343	)		(1,475,389	)		14,167,893			(21,628,448	)
Net income (loss):
By segment		Ps. (150,388,699	)		(44,599,751	)		(358,862	)		345,913			(40,300,942	)		(8,616,130	)		(5,866,542	)		5,200,268			(292,266,613	)
Less unrealized intersegment sales		—			(1,223,752	)		—			(3,236,935	)		—			(26,886	)		—			(75,530	)		—
Less unrealized gain due to production cost valuation of inventory		(496,329	)		(9,017,791	)		—			2,932,663			—			—			—			(246,594	)		—
Less capitalized refined products		(574,381	)		—			—			—			—			—			—			—			—
Less equity method elimination		303,044			(945,369	)		266,769			—			333			1,238,018			1,201,367			7,166,957			—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			—			—
Less depreciation and impairment of revaluated transferred assets, net of deferred taxes		—			—			—			1,223,919			39,466,660			3,134,974			3,223,449			—			—
Total consolidated net (loss) income		Ps. (151,037,384	)		(55,786,663	)		(92,093	)		1,265,560			(833,949	)		(4,270,024	)		(1,441,726	)		12,045,101			(292,266,613	)
Assets:
By segment		Ps. 2,084,553,745			912,770,881			179,807			28,256,876			276,537,764			17,689,305			35,498,783			195,538,239			2,111,740,735
Less unrealized intersegment sales		858,094			(5,389,977	)		—			—			7,183			—			(5,303	)		(408,059	)		—
Less unrealized gain due to production cost valuation of inventory		(3,657,242	)		(42,379,229	)		—			—			—			(26,886	)		—			(7,163,664	)		—
Less capitalized refined products		(574,381	)		—			—			—			—			—			—			—			—
Less depreciation and impairment of revaluated transferred assets, net of deferred taxes		(22,503,168	)		—			—			(2,036,128	)		(84,557,831	)		(2,165,068	)		(9,522,686	)		(424,849	)		—
Less equity method for unrealized profits		(759,624	)		(7,813,492	)		—			—			(91,123	)		(6,573,895	)		(2,828,749	)		(732,768	)		—
Less amortization of capitalized interest		118,981			8,123			—			—			—			—			—			—			—
Total consolidated assets		Ps. 2,058,036,405			857,196,306			179,807			26,220,748			191,895,993			8,923,456			23,142,045			186,808,899			2,111,740,735
Liabilities:
By segment		Ps. 2,570,412,398			1,081,528,677			531,580			13,186,297			56,706,251			6,556,050			2,308,890			116,648,398			3,587,988,972
Less unrealized intersegment sales		—			(4,419,929	)		—			700,127			—			—			—			194,483			—
Total consolidated liabilities		Ps. 2,570,412,398			1,077,108,748			531,580			13,886,424			56,706,251			6,556,050			2,308,890			116,842,881			3,587,988,972

As of/for the year ended December 31, 2016	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies
Sales:
By segment		Ps. 616,380,615			771,597,427			184,434			6,263,093			71,130,845			4,775,775			17,217,131			800,979,076			53,803,095
Less unrealized intersegment sales		—			(847,432	)		—			(4,211,227	)		—			—			—			(331,446	)		—
Total consolidated sales		Ps. 616,380,615			770,749,995			184,434			2,051,866			71,130,845			4,775,775			17,217,131			800,647,630			53,803,095
Operating income (loss):
By segment		Ps. 503,679,153			(60,347,367	)		(22,645	)		1,271,202			(25,701,065	)		(2,877,725	)		(3,504,812	)		19,526,997			(14,909,525	)
Less unrealized intersegment sales		—			(847,432	)		—			(4,211,227	)		—			—			—			(331,446	)		—
Less unrealized gain due to production cost valuation of inventory		(273,237	)		3,572,498			—			3,815,371			—			905,910			(2,163	)		(213,069	)		—
Less capitalized refined products		(1,661,986	)		(7,904,259	)		—			—			—			—			—			—			—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			—			—
Less depreciation and impairment of revaluated assets		—			—			—			640,702			6,899,211			357,455			5,544,830			—			—
Total consolidated operating income (loss)		Ps. 501,862,911			(65,526,560	)		(22,645	)		1,516,048			(18,801,854	)		(1,614,360	)		2,037,855			18,982,482			(14,909,525	)
Net income (loss):
By segment		Ps. (44,069,001	)		(61,639,067	)		(381,214	)		(387,250	)		(16,917,356	)		(7,820,835	)		(3,780,706	)		11,711,265			(194,251,296	)
Less unrealized intersegment sales		—			(847,432	)		—			(4,211,227	)		—			—			—			(331,446	)		—
Less unrealized gain due to production cost valuation of inventory		(273,237	)		3,572,498			—			3,815,371			—			905,910			(2,163	)		(213,069	)		—
Less capitalized refined products		(1,661,986	)		(7,904,259	)		—			—			—			—			—			—			—
Less equity method elimination		6,590			(3,047,030	)		346,514			—			—			4,897,988			334,653			—			—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			—			—
Less depreciation of revaluated assets		—			—			—			640,702			6,899,211			357,455			5,544,830			—			—
Total consolidated net (loss) income		Ps. (45,878,653)			(69,865,290	)		(34,700	)		(142,404	)		(10,018,145	)		(1,659,482	)		2,096,614			11,166,750			(194,251,296	)
Assets: By segment		Ps.2,232,052,453			1,151,907,566			425,141			30,990,147			254,615,026			10,421,225			43,067,636			170,782,928			2,359,024,145
Less unrealized intersegment sales		483,230			(4,158,101	)		—			—			—			—			(5,304	)		(332,529	)		—
Less unrealized gain due to production cost valuation of inventory		(3,246,782	)		(33,361,438	)		—			—			—			—			—			(5,688,341	)		—
Less capitalized refined products		(1,661,986	)		—			—			—			—			—			—			—			—
Less depreciation of revalued assets		(20,585,300	)		—			—			(3,316,549	)		(123,790,105	)		(5,300,044	)		(12,746,136	)		(652	)		—
Less equity method for unrealized profits		(742,055	)		(7,293,447	)		(36,718	)		—			—			4,435,288			(4,308,877	)		(8,960,344	)		—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			(424,198	)		—
Total consolidated assets		Ps.2,206,418,541			1,107,094,580			388,423			27,673,598			130,824,921			9,556,469			26,007,319			155,376,864			2,359,024,145
Liabilities:
By segment		Ps.2,533,221,665			1,282,558,220			664,829			16,457,347			29,336,417			3,015,450			3,901,722			85,392,123			3,553,477,189
Less unrealized intersegment sales		—			(4,419,930	)		—			395,855			—			—			—			1,493,766			—
Total consolidated liabilities		Ps.2,533,221,665			1,278,138,290			664,829			16,853,202			29,336,417			3,015,450			3,901,722			86,885,889			3,553,477,189

As of/for the year ended December 31, 2015	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services		Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies
Sales:
By segment	Ps.	690,642,133			874,630,488			—			1,511,970		10,954,841			1,704,684			5,048,600			761,213,475			18,801,547
Less unrealized intersegment sales		—			(597,212	)		—			—		—			—			(5,304	)		(200,197	)		—
Total consolidated sales	Ps.	690,642,133			874,033,276			—			1,511,970		10,954,841			1,704,684			5,043,296			761,013,278			18,801,547
Operating income (loss):
By segment	Ps.	(89,473,302	)		(88,819,558	)		(51,911	)		700,748		(6,875,252	)		(262,145	)		(2,288,747	)		10,334,138			2,651,449
Less unrealized intersegment sales		—			(597,212	)		—			—		—			—			(5,304	)		(200,197	)		—
Less unrealized gain due to production cost valuation of inventory		(251,995	)		21,681,180			—			—		—			—			2,163			494,727			—
Less capitalized refined products		(3,496,201	)		—			—			—		—			—			—			—			—
Less amortization of capitalized interest		118,980			—			—			—		—			—			—			—			—
Less depreciation and impairment of revaluated assets		—			—			—			95,811		1,192,250			117,141			531,745			—			—
Total consolidated operating (loss) income	Ps.	(93,102,518	)		(67,735,590	)		(51,911	)		796,559		(5,683,002	)		(145,004	)		(1,760,143	)		10,628,668			2,651,449
Net income (loss):
By segment	Ps.	(663,719,119	)		(107,164,261	)		(57,310	)		359,621		(4,877,610	)		(262,242	)		(2,314,774	)		8,402,644			(711,312,155	)
Less unrealized intersegment sales		—			(597,212	)		—			—		—			—			(5,304	)		(200,197	)		—
Less unrealized gain due to production cost valuation of inventory		(251,995	)		21,681,180			—			—		—			—			2,163			494,727			—
Less capitalized refined products		(3,496,201	)		—			—			—		—			—			—			—
Less equity method elimination		(45,679	)		(1,129,042	)		—			—		—			—			30,953			—			—
Less amortization of capitalized interest		118,980			—			—			—		—			—			—			—			—
Less depreciation of revaluated assets		—			—			—			95,811		1,192,250			117,141			531,745			—			—
Total consolidated net (loss) income	Ps.	(667,394,014	)		(87,209,335	)		(57,310	)		455,432		(3,685,360	)		(145,101	)		(1,755,217	)		8,697,174			(711,312,155	)

Supplemental geographic information:

	For the years ended December 31,
	2017		2016		2015
Domestic sales	Ps.	877,360,038	Ps.	670,000,473	Ps.	746,235,912
Export sales:
United States		302,912,999		221,954,461		266,826,499
Canada, Central and South America		13,943,080		14,058,897		11,027,813
Europe		71,470,613		64,348,997		58,707,787
Other		120,212,420		94,755,762		70,652,346
Total export sales		508,539,112		395,118,117		407,214,445
Services income		11,130,569		8,974,642		8,310,035
Total sales	Ps.	1,397,029,719	Ps.	1,074,093,232	Ps.	1,161,760,392

PEMEX does not have significant long-lived assets outside of Mexico.

The following table shows income by product:

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Cash, Cash Equivalents and Restricted Cash

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Cash, Cash Equivalents and Restricted Cash

NOTE 6. CASH, CASH EQUIVALENTS AND RESTRICTED CASH

a. As of December 31, 2017 and 2016, cash and cash equivalents were as follows:

	2017		2016
Cash on hand and in banks(i)	Ps.	55,871,127	Ps.	71,430,427
Highly liquid investments(ii)		41,980,627		92,102,086
	Ps.	97,851,754	Ps.	163,532,513

(i) Cash on hand and in banks is primarily composed of cash in banks.

(ii) Mainly composed of short-term Mexican Government investments.

b. At December 31, 2017 and 2016, restricted cash was as follows:

	2017		2016
Restricted cash		Ps.               —	Ps.	10,478,626

Restricted cash as of December 31, 2016 was primarily composed of the deposit made by Pemex Exploration and Production in the amount of U.S. $465,060, plus interests as a result of an arbitration claim filed by Corporación Mexicana de Mantenimiento Integral, S. de R.L. de C.V. (“COMMISA”) before the International Court of Arbitration of the International Chamber of Commerce (the “ICA”). On April 6, 2017, Pemex Exploration and Production and Petróleos Mexicanos executed a settlement agreement with COMMISA and agreed to pay COMMISA U.S. $435,000, plus the applicable VAT with the funds deposited by Pemex Exploration and Production in a bank account as a guarantee before the U.S. District Court for the Southern District of New York and through a wire transfer.

During 2016, PMI HBV made deposits of U.S. $41,319, in an account in Banco Santander, S.A. as additional collateral for a credit agreement in accordance with the terms of the agreement. The credit agreement required that PMI HBV maintain a loan-to-value ratio based on the ratio between the principal amount of debt and the market value in U.S. dollars of the Repsol S. A. (“Repsol”) shares owned by PMI HBV. Due to the increase in the value of Repsol shares, the deposit was reimbursed to PMI HBV; therefore, beginning June 30, 2017, no restricted cash was held. On October 20, 2017, PMI HBV prepaid the balance of the credit agreement in order to sell all of its shares in Repsol.

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Accounts Receivable, Net

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Accounts Receivable, Net

NOTE 7. ACCOUNTS RECEIVABLE, NET

As of December 31, 2017 and 2016, accounts receivable and other receivables were as follows:

	2017		2016
Domestic customers, net	Ps.	60,057,141	Ps.	41,884,579
Export customers, net		54,428,883		34,859,341
Sundry debtors		26,105,703		18,736,922
Taxes to be recovered and prepaid taxes		23,039,023		29,361,303
Employees and officers		5,681,478		6,054,251
Advances to suppliers		1,250,846		2,246,437
Other accounts receivable		82,160		77,694
	Ps.	170,645,234	Ps.	133,220,527

The following table shows a breakdown of accounts receivable based on their credit history at December 31, 2017 and 2016:

	Domestic customers
	2017			2016
1 to 30 days	Ps.	10,188,070			Ps.1,767,718
31 to 60 days		4,081,862			658,456
61 to 90 days		777,409			263,447
More than 90 days(i)		11,345,933			1,016,553
Past due		26,393,274			3,706,174
Impaired (reserved)		(951,932	)		(458,428	)
Unimpaired		25,441,342			3,247,746
Current		34,615,799			38,636,833
Total	Ps.	60,057,141			Ps.41,884,579

⁽ⁱ⁾ The increase in 2017 in accounts receivable invoices more than 90 days old is primarily due to the termination of the outstanding balances compensation system in place between Mexican Government owned companies.

	Export customers
	2017			2016
1 to 30 days	Ps.	334,155		Ps.	341,184
31 to 60 days		—			6,824
61 to 90 days		—			35,372
More than 90 days		315,888			624,157
Past due		650,043			1,007,537
Impaired (reserved)		(272,813	)		(374,699	)
Unimpaired		377,230			632,838
Current		54,051,653			34,226,503
Total	Ps.	54,428,883		Ps.	34,859,341

Additionally, the reconciliation for impaired accounts receivable is as follows:

	Domestic customers
	2017			2016
Balance at the beginning of the year		Ps. (458,428	)		Ps. (667,883	)
Additions against income		(493,514	)		(218,836	)
Amount used		10			428,291
Balance at the end of the year		Ps. (951,932	)		Ps. (458,428	)
	Export customers
	2017			2016
Balance at the beginning of the year		Ps. (374,699	)		Ps. (312,004	)
Additions against income		(204,713	)		(25,931	)
Amount used		297,047			—
Translation effects		9,552			(36,764	)
Balance at the end of the year		Ps. (272,813)			Ps. (374,699)

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Inventories, Net

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Inventories, Net

NOTE 8. INVENTORIES, NET

As of December 31, 2017 and 2016, inventories were as follows:

	2017		2016
Refined and petrochemicals products		Ps. 27,862,384		Ps. 21,534,846
Products in transit		19,112,606		7,735,163
Crude oil		11,445,780		11,391,310
Materials and products in stock		5,172,779		4,721,834
Materials in transit		180,711		419,547
Gas and condensate products		84,670		89,360
		Ps. 63,858,930		Ps. 45,892,060

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Held-for-Sale Non-Financial Assets

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Held-for-Sale Non-Financial Assets

NOTE 9. HELD—FOR—SALE NON-FINANCIAL ASSETS

Pursuant to Round Zero, PEMEX was provisionally assigned titles to certain blocks in escrow. The ownership of the fixed assets located in those blocks is transferred when the blocks are awarded to third parties in subsequent rounds.

As a result of the Energy Reform Decree, the secondary legislation and the corresponding initial adjudication of rights for the exploration and extraction of oil and solid hydrocarbons addressed in transitory article 6 of the Energy Reform Decree, certain assignments that Pemex Exploration and Production received from the Mexican Government were affected. The Mexican Government will compensate PEMEX for these investments at fair value pursuant to the terms determined by the Ministry of Energy.

In 2016, pursuant to Round 1.3, the Ministry of Energy awarded certain contractual areas for the exploration and extraction of oil and solid hydrocarbons to third parties and their respective fixed assets have been transferred from PEMEX to such third parties. During 2016, PEMEX submitted the application for compensation from the Ministry of Energy for the fixed assets located in those areas, receiving resolution in 2017.

All the assets that are part of unassigned areas to PEMEX as part of Round Zero continue to be classified as long-lived assets, subject to all regulations applicable to such assets, provided PEMEX (1) obtains the economic benefits derived from the use thereof and (2) at the same time exercises control over them and assumes the benefits and risks associated with such assets.

Assets that are part of the areas that were not assigned to PEMEX as part of Round Zero, and from which PEMEX does not obtain economic benefits derived from use of such assets, are written down, affecting the results for that year.

As a result, of the Ps. 7,460,674 held-for-sale, the non-financial assets at December 31, 2016, Ps.4,652,314 were reclassified to fixed assets and the remaining Ps. 2,808,360, were transferred to the results of the year.

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Available-for-Sale-Financial Assets

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Available-for-Sale-Financial Assets

NOTE 10. AVAILABLE—FOR—SALE—FINANCIAL ASSETS

a. On January 1, 2016, PEMEX had a total of 20,724,331 shares of Repsol valued at Ps. 3,944,696, which represented approximately 1.48% of Repsol’s share capital.

On January 15, 2016, PMI HBV received 942,015 new Repsol shares valued at Ps. 188,490 as an in-kind dividend that was declared on December 31, 2015.

On June 13, 2016, Repsol declared flexible dividends to its shareholders, of which PMI HBV received 555,547 new Repsol shares as an in-kind dividend on July 18, 2016, valued at Ps. 128,051.

Since the 1,497,562 new Repsol shares were received as an in-kind dividend during 2016, they were not included in the loan agreement obtained by PMI HBV in August 2015 and these shares are presented as short-term available-for-sale financial assets amounting to Ps. 435,556. These shares were sold in January 2017.

On December 14, 2016, Repsol declared flexible dividends to its shareholders, of which PMI HBV received 584,786 new Repsol shares as an in-kind dividend in January 23, 2017. This amount was recognized as an account receivable of Ps.165,346 as of December 31, 2016.

As of December 31, 2016, the investment in 20,724,331 shares of Repsol held by PMI HBV was valued at Ps. 6,027,540. These shares are presented under non-current assets. The effect of the valuation on the investment at fair value was recorded in other comprehensive result in the consolidated statement of changes in equity (deficit) as a profit of Ps. 207,817 at December 31, 2016.

On January 24, 2017 and January 25, 2017, PMI HBV sold a total of 2,082,348 Repsol shares at an average price of € 14.17 per share, for a total amount of Ps. 684,029. These shares were not included as collateral on the loan agreement.

On June 7, 2017, Repsol declared flexible dividends to its shareholders, of which PMI HBV received 609,539 new Repsol shares as an in-kind dividend on July 13, 2017. This amount was recognized as an account receivable of Ps. 180,729.

On October 26, 2017, PMI HBV sold 21,333,870 Repsol shares for a total amount of Ps. 7,342,807 pursuant to a share forward transaction with Credit Agricole CIB. This sale, together with the sale on January 24 and 25, 2017, resulted in a total loss of Ps. 3,523,748.

As a result of the above, PEMEX does not have an equity interest in Repsol as of December 31, 2017. The 2016 balance allocated in other comprehensive income for Ps. 5,564,130 was transferred to the results of the year.

b. As of December 31, 2016, due to the loss of significant influence in TAG Norte Holding, S. de R. L. de C. V. and TAG Pipelines Sur, S. de R. L. de C. V., these companies were valued at fair value and are presented as short-term available-for-sale financial assets in the amount of Ps.2,417,123.

As of December 31, 2017, PEMEX is in the process of selling its shares of TAG Norte Holding, S. de R.L. de C.V. and TAG Pipeline Sur, S. de R.L. de C.V. These shares have been classified as available-for-sale-financial-assets and have been valued at their net realizable value, which as of December 31, 2017 has resulted in a negative value that has been recognized in the profit or loss at the end of the year. As of the date of these consolidated financial statements, PEMEX is in the process of selling these shares. As of December 31, 2017, available-for-sale current non-financial assets amounted Ps. 1,056,918.

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Investments in Joint Ventures and Associates

12 Months Ended

Dec. 31, 2017

Investments Schedule [Abstract]

Investments in Joint Ventures and Associates

NOTE 11. INVESTMENTS IN JOINT VENTURES AND ASSOCIATES

The investments in joint ventures and associates as of December 31, 2017 and 2016, were as follows:

		Percentage of investment		December 31,
				2017		2016
Deer Park Refining Limited			49.99%		Ps.14,405,542		Ps.14,039,384
Petroquímica Mexicana de Vinilo, S. A. de C. V.	(i)		44.09%		—		4,309,050
Sierrita Gas Pipeline LLC			35.00%		1,084,169		1,112,338
Frontera Brownsville, LLC.			50.00%		471,085		478,414
CH4 Energía, S. A.			50.00%		315,713		194,868
Texas Frontera, LLC.			50.00%		239,782		260,828
Administración Portuaria Integral de Dos Bocas, S.A. de C.V.			40.00%		64,328		139,523
PMV Minera, S.A. de C.V.			44.09%		45,133		61,779
Ductos el peninsular, S.A.P.I de C. V.			50.00%		18,336		18,626
Other-net			Various		63,276		122,699
					Ps.16,707,364		Ps.20,737,509

i. On April 20, 2016, an explosion occurred in the “Planta de Clorados 3” (Chlorinated Plant 3) of the Petroquímica Mexicana de Vinilo, resulting in approximately U.S. $ 461,000 in damages. Chorinated Plant 3 incurred the greatest amount of damage, including the loss of certain assets and the closure of the plant for an undefined amount of time. The Chlorine-Soda plants and the ethylene plants did not register any damage. On December 20, 2017, Petroquímica Mexicana de Vinilo permanently closed the plant, and -the full book value was written-off impacting the value of this investment.

Profit (loss) sharing in joint ventures and associates:

	2017			2016			2015
Deer Park Refining Limited		Ps. 920,409			Ps. 1,437,850			Ps. 1,913,835
Ductos y Energéticos del Norte, S.A. de C.V.(i)		360,092			—			—
CH4 Energía S.A. de C.V.		125,132			—			—
Sierrita Gas Pipeline LLC		129,401			105,825			152,445
PMV Minera, S.A. de C.V.		6,253			—			—
Petroquímica Mexicana de Vinilo, S. A. de C. V.		(1,223,640	)		(190,468	)		(61,952	)
Administración Portuaria Integral de Dos Bocas, S.A. de C.V.		(75,195	)		—			—
Gasoductos de Chihuahua, S. de R. L. de C. V. (ii)		—			638,126			666,779
Compañía Mexicana de Exploraciones, S. A. de C. V.(iii)		—			—			(496,774	)
Other, net		117,988			144,512			143,782
Profit sharing in joint ventures and associates, net		Ps. 360,440			Ps. 2,135,845			Ps. 2,318,115

i. In November 2017, PEMEX sold its 50% interest in Ductos y Energéticos del Norte, S. de R.L. de C. V., to Infraestructura Energética Nova, S.A.B. of C.V. for a total of U.S. $ 3,141,710, yielding a profit of Ps. 3,139,103.

ii. On September 28, 2016, PEMEX completed the divestiture of its 50% ownership interest in the Gasoductos de Chihuahua S. de R.L. de C.V. joint venture with Infraestructura Energética Nova, S.A.B. de C.V. The stock was sold for Ps. 22,684,736, yielding a profit of Ps. 15,211,039.

iii. Beginning July 1, 2016 this company was included in the consolidated financial statements of PEMEX. Until June 30, 2016 this Company was accounted for as an investment in an associate under the equity method (see Note 3-a).

The following tables show condensed financial information of major investments recognized under the equity method during 2017 and 2016:

Condensed statements of financial position
	Deer Park Refining Limited				Sierrita Gas Pipeline, LLC
	2017		2016		2017		2016
Total assets		Ps. 41,075,547		Ps. 42,428,275		Ps.3,518,036		Ps.3,244,811
Total liabilities		Ps. 12,261,581		Ps. 14,346,643		Ps.   420,410		Ps.     66,703
Total equity		28,813,966		28,081,632		3,097,626		3,178,108
Total liabilities and equity		Ps.41,075,547		Ps. 42,428,275		Ps.3,518,036		Ps.3,244,811

Condensed statements of comprehensive income

Deer Park Refining Limited

Sierrita Gas Pipeline, LLC

Gasoductos de Chihuahua, S. de R. L. de C. V.

December 31,

December 31,

August 31,

December 31,

2017

2016

2015

2017

2016

2016

2015

Sales and other income

Ps.16,427,064

Ps.16,750,155

Ps.16,658,705

Ps. 840,414

Ps. 717,351

Ps.3,798,666

Ps.4,617,982

Costs and expenses

14,586,061

13,874,172

12,830,653

470,697

414,994

2,522,415

3,284,424

Net result

Ps. 1,841,003

Ps. 2,875,983

Ps. 3,828,052

Ps. 369,717

Ps. 302,357

Ps.1,276,251

Ps.1,333,558

Additional information about the significant investments in joint ventures and associates is presented below:

• Deer Park Refining Limited. On March 31, 1993, PMI NASA acquired 50% of the Deer Park Refinery. In its capacity as general partner of Deer Park Refining Limited Partnership, Shell is responsible for the operation and management of the refinery, the purpose of which is to provide oil refinery services to PMI NASA and Shell for a processing fee. Shell is responsible for determining the crude oil and production materials requirements and both partners are required to contribute in equal amounts. Deer Park returns to PMI NASA and Shell products in the same amounts. Shell is responsible for purchasing the total amount of finished products in stock at market prices. This joint venture is recorded under the equity method.

• Petroquímica Mexicana de Vinilo, S.A. de C.V. On September 13, 2013, Pemex-Petrochemicals (now Pemex Industrial Transformation), through its subsidiary PPQ Cadena Productiva, S.L. and Mexichem founded Petroquímica Mexicana de Vinilo, S.A. de C.V. (Mexicana de Vinilo). The principal activity of Petroquímica Mexicana de Vinilo, S.A. de C.V. is the production and sale of chemicals. Mexicana de Vinilo’s main products are chlorine, caustic soda, ethylene and monomers of vinyl chloride. Mexichem has been responsible for operational and financial decisions for Petroquímica Mexicana de Vinilo. This investment is recorded under the equity method. Due to the damage caused by an accident that occurred in April 2016, Petroquímica Mexicana de Vinilo decided to permanently close the plant.

• Sierrita Gas Pipeline LLC. This company was created on June 24, 2013. Its main activity is the developing of projects related to the transportation infrastructure of gas in the United States. This investment is recorded under the equity method.

• Frontera Brownsville, LLC. Effective April 1, 2011, PMI SUS entered into a joint venture with TransMontaigne Operating Company L.P (TransMontaigne) to create Frontera Brownsville, LLC. Frontera Brownsville, LLC was incorporated in Delaware, United States, and has the corporate power to own and operate certain facilities for the storage and treatment of clean petroleum products. This investment is recorded under the equity method.

• Texas Frontera, LLC. This company was constituted on July 27, 2010, and its principal activity is the lease of tanks for the storage of refined product. PMI SUS, which owns 50% interest in Texas Frontera, entered into a joint venture with Magellan OLP, L.P. (Magellan), and together they are entitled to the results in proportion of their respective investment. As of December 31, 2016, the company has seven tanks with a capacity of 120,000 barrels per tank. This joint venture is recorded under the equity method.

• CH4 Energía, S.A. This company was constituted on December 21, 2000. CH4 Energía engages in the purchase and sale of natural gas and in activities related to the trading of natural gas, such as transport and distribution in Valle de Toluca, México. This joint venture is recorded under the equity method.

• Administración Portuaria Integral de Dos Bocas, S.A. de C.V. This company was constituted on August 12, 1999. Its primary activity is adminitrating the Dos Bocas port, which is in Mexico’s public domain, promoting the port’s infrastructure and providing related port services. This investment is recorded under the equity method.

• PMV Minera, S.A. de C.V. This company was constituted on October 1, 2014 and the principal activity is the extraction and sale of salmuera (mixture of salt and water). This investment is recorded under the equity method.

• Gasoductos de Chihuahua, S. de R.L. de C.V. On February 6, 1997, Pemex Industrial Transformation (formerly Pemex-Refining) entered into a joint venture with IEnova Gasoductos Holding, S. de R.L de C.V. to own and operate companies related to gas transportation and distribution, called Gasoductos de Chihuahua, S. de R.L. de C.V. Decision-making requires the consent of both partners. The participation of each of the partners was 50% of the share capital. This investment was recorded under the equity method until August 2016, when PEMEX completed the divestiture of this company as described in footnote (ii) to the table above.

• Compañía Mexicana de Exploraciones S.A. de C.V., (“COMESA”). COMESA was founded on November 12, 1968 to support PEMEX’s exploration programs. The operations of COMESA are focused on designing integral solutions for the energy sector, along the value chain for exploration and production, refining, petrochemicals, geothermal energy and other energy areas all over the energy sector in Mexico, South America and the United States. COMESA’s principal activities are: gravimetric, magnetometric and microseismic studies, land seismic data acquisition (2D,3D, 3C), marine Seismic data acquisition, seismic data processing, seismic data interpretation and integration, vertical Seismic Profile (VSP) 2D and 3D, reservoir characterization and visualization, conceptualization and definition for the exploration process. Until June 30, 2016 this company was accounted under the equity method. As of July 1, 2016 this company is included in the consolidated results.

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Wells, Pipelines, Properties, Plant and Equipment, Net

12 Months Ended

Dec. 31, 2017

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Wells, Pipelines, Properties, Plant and Equipment, Net

NOTE 12. WELLS, PIPELINES, PROPERTIES, PLANT AND EQUIPMENT, NET

	Plants			Drilling equipment			Pipelines			Wells			Buildings			Offshore platforms			Furniture and equipment			Transportation equipment			Construction in progress			Land			Unproductive fixed assets			Other fixed assets			Total fixed assets
Investment
Balances as of January 1, 2016		Ps. 648,412,014			21,680,343			419,979,508			1,066,515,651			66,284,466			260,328,096			52,966,194			15,329,095			211,675,597			43,347,802			—			630,878			2,807,149,644
Acquisitions		20,406,464			1,629,710			1,265,011			8,239,480			2,541,802			9,866,984			545,271			2,063,519			107,682,868			1,487,434			6,800			—			155,735,343
Reclassifications		150,817			—			(1,268,887	)		8,649,686			(6,610,184	)		—			(561,569	)		(325,778	)		(282,044	)		50,709			2,039			(137,246	)		(332,457	)
Capitalization		15,943,630			—			11,851,378			40,825,973			1,085,323			17,318,279			2,769			2,918,621			(89,945,973	)		—			—			—			—
Impairment		81,135,967			—			31,967,407			198,974,994			—			35,640,491			438,979			8,743			(16,852,238	)		—			—			—			331,314,343
Disposals		(7,602,782	)		(40,937	)		(3,648,989	)		(4,382,867	)		(558,374	)		(449,645	)		(2,644,957	)		(551,355	)		(4,864,062	)		(314,327	)		(8,839	)		(2,126	)		(25,069,260	)
Balances as of December 31, 2016		758,446,110			23,269,116			460,145,428			1,318,822,917			62,743,033			322,704,205			50,746,687			19,442,845			207,414,148			44,571,618			—			491,506			3,268,797,613
Acquisitions		10,018,030			418,283			7,054,793			14,937,882			802,300			7,811,374			1,183,679			284,445			51,410,469			58,563			—			—			93,979,818
Reclassifications		3,146,955			—			(53,349	)		—			98,245			(10,199,213	)		(96,899	)		(75,674	)		(812,943	)		(560	)		—			4,072,464			(3,920,974	)
Capitalization		43,033,864			—			21,357,074			36,564,811			1,265,246			8,677,765			30,879			3,746,395			(114,700,828	)		29,248			—			(4,454	)		—
Impairment		(48,020,616	)		—			2,226,771			(83,236,991	)		—			(15,564,190	)		—			—			(6,849,534	)		—			—			—			(151,444,560	)
Disposals		(10,598,983	)		(244,283	)		(8,862,541	)		(19,340,709	)		(208,353	)		—			(806,694	)		(226,375	)		(6,724,930	)		(112,170	)		—			(4,440,865	)		(51,565,902	)
Balances as of December 31, 2017		Ps. 756,025,360			23,443,116			481,868,176			1,267,747,910			64,700,471			313,429,941			51,057,652			23,171,636			129,736,382			44,546,699			—			118,651			3,155,845,995
Accumulated depreciation and amortization
Balances as of January 1, 2016		Ps.(321,283,906	)		(578,015	)		(139,331,407	)		(780,443,639	)		(37,712,087	)		(140,908,960	)		(36,513,479	)		(5,894,520	)		—			—			—			—			(1,462,666,013	)
Depreciation and amortization		(44,549,443	)		(2,364,560	)		(15,153,879	)		(70,090,038	)		(1,796,383	)		(12,252,810	)		(3,205,089	)		(1,027,289	)		—			—			—			—			(150,439,491	)
Reclassifications		(10,521	)		—			(166,632	)		(3,077	)		(108,718	)		—			166,914			454,492			—			—			—			—			332,458
Disposals		5,826,891			—			2,286,691			—			492,557			—			2,560,988			550,554			—			—			—			—			11,717,681
Balances as of December 31, 2016		(360,016,979	)		(2,942,575	)		(152,365,227	)		(850,536,754	)		(39,124,631	)		(153,161,770	)		(36,990,666	)		(5,916,763	)		—			—			—			—			(1,601,055,365	)
Depreciation and amortization		(45,709,123	)		(2,198,867	)		(15,095,115	)		(74,673,473	)		(1,906,164	)		(13,192,369	)		(2,890,563	)		(1,038,839	)		—			—			—			—			(156,704,513	)
Reclassifications		2,799,244			—			(72,841	)		—			(69,236	)		1,146,904			102,375			14,532			—			—			—			—			3,920,978
Disposals		8,902,711			127,458			7,573,769			16,810,591			59,022			—			805,916			222,764			—			—			—			—			34,502,231
Balances as of December 31, 2017		Ps.(394,024,147	)		(5,013,984	)		(159,959,414	)		(908,399,636	)		(41,041,009	)		(165,207,235	)		(38,972,938	)		(6,718,306	)		—			—			—			—			(1,719,336,669	)
Wells, pipelines, properties, plant and equipment—net as of December 31, 2016		Ps. 398,429,131			20,326,541			307,780,201			468,286,163			23,618,402			169,542,435			13,756,021			13,526,082			207,414,148			44,571,618			—			491,506			1,667,742,248
Wells, pipelines, properties, plant and equipment—net as of December 31, 2017		Ps. 362,001,214			18,429,132			321,908,762			359,348,274			23,659,462			148,222,706			12,084,714			16,453,330			129,736,382			44,546,699			—			118,651			1,436,509,326
Depreciation rates		3 to 5	%		5	%		2 to 7	%		—			3 to 7	%		4	%		3 to 10	%		4 to 20	%		—			—			—			—			—
Estimated useful lives		20 to 35			20			15 to 45			—			33 to 35			25			3 to 10			5 to 25			—			—			—			—			—

a. As of December 31, 2017, 2016 and 2015, the financing cost identified with fixed assets in the construction or installation stage, capitalized as part of the value of such fixed assets, was Ps. 3,060,963, Ps. 3,667,752 and Ps. 5,258,854, respectively.

b. The combined depreciation of fixed assets and amortization of wells for the fiscal years ended December 31, 2017, 2016 and 2015, recognized in operating costs and expenses, was Ps.156,704,513, Ps. 150,439,491 and Ps. 167,951,250, respectively, which includes costs related to plugging and abandonment of wells for the years ended December 31, 2017, 2016 and 2015 of Ps. 850,015, Ps. 1,698,312, and Ps. 1,401,870, respectively.

c. As of December 31, 2017 and 2016, provisions relating to future plugging of wells costs amounted to Ps. 68,797,600 and Ps. 64,967,710, respectively, and are presented in the “Provisions for plugging of wells” (see Note 18).

d. As of December 31, 2017 and 2016, acquisitions of property, plant and equipment include transfers from wells unassigned to a reserve for Ps. 16,440,645 and Ps. 16,393,773, respectively (see Note 13) and Ps. 4,652,314 from available-for-sale non-financial assets as of December 31, 2017 (see Note 9).

e. As of December 31, 2017 and 2016, PEMEX recognized a net impairment of Ps. 151,444,560 and a net reversal of impairment of Ps. 331,314,343, respectively, which is presented as a separate line item in the consolidated statement of comprehensive income as follows:

i. As of December 31, 2017, the net impairment was as follows:

	Impairment			Reversal of impairment		Net Impairment
Pemex Exploration and Production	Ps.	(129,350,315	)	Ps.	—	Ps.	(129,350,315	)
Pemex Industrial Transformation		(19,751,882	)		3,799,790		(15,952,092	)
AGRO		(4,206,653	)		—		(4,206,653	)
Pemex Fertilizers		(1,935,500	)		—		(1,935,500	)
Total	Ps.	(155,244,350	)	Ps.	3,799,790	Ps.	(151,444,560	)

Cash Generating Unit of Pemex Exploration and Production

Pemex Exploration and Production recognized an impairment in the amount of Ps. 129,350,315 as of December 31, 2017, arising from: (i) the deferral of the development investments in the first 5 years of the economic horizon in the proved reserves, which caused a decrease in production and consequently in income, as well as the re-categorization of part of the proved reserves as probable reserve, as a consequence of budget adjustments in the strategic investments in the Cantarell, Aceite terciario del Golfo, Crudo Ligero Marino, Antonio J. Bermúdez and Tzimin Xux projects, (ii) insufficient cash flows to make up for costs recovery at the Burgos and Lakach projects as a resulting from the appreciation of the Mexican peso against the U.S. dollar by 4.3%, from a peso—U.S. dollar exchange rate of Ps. 20.6640 to U.S. $1.00 as of December 31, 2016 to a peso—U.S. dollar exchange rate of Ps. 19.7867 to U.S. $1.00 as of December 31, 2017, given that cash inflows are denominated in U.S. dollars and then translated to the reporting currency using the exchange rate at the date of report; (iii) a 0.3% increase in the discount rate; (iv) a 7.2% decrease in crude oil forward prices from 60.24 usd/bl in 2016 to 55.89 usd/bl in 2017 and (v) the natural decline in production in the Macuspana project.

The cash generating units of Pemex Exploration and Production are investment projects in productive fields with hydrocarbon reserves associated with proved reserves (1P). These productive hydrocarbon fields contain varying degrees of heating power consisting of a set of wells and are supported by fixed assets associated directly with production, such as pipelines, production facilities, offshore platforms, specialized equipment and machinery.

Each project represents the smallest unit which can concentrate the core revenues, with clear costs and expenses that enable future cash flows (value in use) to be determined.

To determine the value in use of long-lived assets associated with hydrocarbon extraction, the net present value of reserves is determined based on the following assumptions:

Average crude oil price	55.89 U.S. dollars/bl
Average gas price	4.92 U.S. dollars /mpc
Average condensates price	38.33 U.S. dollars /bl
Discount rate	14.40% annually

The total forecast production, calculated with a horizon of 25 years is 7,091 million bpce.

Pemex Exploration and Production determines the recoverable amount of fixed assets based on the long-term estimated prices for Pemex Exploration and Production’s proved reserves (1P). The recoverable amount on each asset is the value in use.

Cash Generating Units of Pemex Industrial Transformation

As of December 31, 2017, Pemex Industrial Transformation recognized a net impairment of Ps. (15,952,092).

The impairment was in the following cash generating units:

Minatitlán Refinery	Ps.	(5,691,005	)
Madero Refinery		(8,480,880	)
Salina Cruz Refinery		(5,579,997	)
Total impairment of assets		(19,751,882	)
Cangrejera Petrochemical Center		3,565,355
Independencia Petrochemical Center		112,292
Arenque gas processor complex		57,039
Matapionche gas processor complex		65,104
Reversal of impairment		3,799,790
Net impairment	Ps.	(15,952,092	)

The impairment was mainly due to (i) an increase in capitalizable maintenance expenses in refining; (ii) the appreciation of the Mexican peso against the U.S. dollar, from a peso—U.S. dollar exchange rate of Ps. 20.6640 to U.S. $1.00 as of December 31, 2016 to a peso—U.S. dollar exchange rate of Ps. 19.7867 to U.S. $1.00 as of December 31, 2017; partially offset by (i) an increase in the transportation fees; (ii) an increase in the processing of wet gas due to higher imports of this product and redistribution by Pemex Exploration and Production; (iii) an increase in prices arising from the price liberalization in 2017; and (iv) a decrease in the discount rate of cash generating units of refined products, gas and petrochemicals of 4.4%, 4.5%, and 5.6%, respectively.

Cash-generating units in Pemex Industrial Transformation are processing centers grouped according to their types of processes as refineries, gas complex processors, and petrochemical centers. These centers produce various finished products for direct sale to customers or intermediate products that can be processed in another of its cash generating units or by a third party. Each processing center of Pemex Industrial Transformation represents the smallest unit which can concentrate the core revenues, with clear costs and expenses that enable future cash flows (value in use) to be determined.

Cash flow determinations are made based on PEMEX’s business plans, operating financial programs, forecasts of future prices of products related to the processes of the cash generating units, budget programs and various statistical models that consider historical information of processes and the capacity of the various processing centers.

To determine the value in use of long-lived assets associated with the cash-generating units of Pemex Industrial Transformation, the net present value of cash flows was determined based on the following assumptions:

	Refining	Gas	Petrochemicals
Average crude oil Price	51.30 U.S. dollars	N.A.	N.A.
Processed volume	767 mbd	3,085 mmpcd or sour gas	Variable because the load inputs are diverse
Rate of U.S. dollar	Ps.19.7867 mxp/usd	Ps.19.7867 mxp/usd	Ps.19.7867 mxp/usd
Useful lives of the cash generating units	Average of 16 years	Average of 9 years	Average of 6 years
Discount rate	11.53% annually	10.24% annually	9.71% annually
Period	2018-2034	2018-2029	2016-2024

The recoverable amount of assets is based on each asset’s value in use. The value in use for each asset is calculated based on cash flows, taking into consideration the volumes to be produced and sales to be carried out. As of December 31, 2017, the value in use for the impairment or reversal of impairment of fixed assets was as follows:

Minatitlán Refinery	Ps. 32,531,925
Madero Refinery	11,420,952
Salina Cruz Refinery	12,051,597
Cangrejera Petrochemical Center	17,544,825
Independencia Petrochemical Center	3,146,413
Arenque gas processor complex	1,283,201
Matapionche gas processor complex	1,074,729
Total value in use	Ps. 79,053,642

Pro-Agroindustria, S.A. de C.V.

Pro-Agroindustria, S.A. de C.V. recognized an impairment for Ps. (4,206,653) related to its nitric acid, amonium nitrate and UAN 32 acquired plants, the rehabilitation of which has not yet commenced. The company will not be able to develop an alternate plan for the rehabilitation of these plants in the following five years due to its financing commitments.

Cash Generating Units of Pemex Fertilizers

Cash generating units are plants used in the ammonia process.

Pemex Fertilizers recognized an impairment of Ps. (1,935,500) for the year ended December 31, 2017 resulting from (i) a decrease in the production capacity in fertilizers plants due to a shortage of raw material; (ii) an increase in raw material prices; and (iii) a decrease in ammonia sale prices.

The recoverable amount of assets is based on each asset’s value in use. To determine cash flows, volumes to be produced and sales to be carried out were taken into consideration. The value in use for the impairment of fixed assets was Ps. 2,744,600. The discount rate used was 9.71%.

ii. As of December 31, 2016, the net reversal of impairment was as follows:

	Impairment			Reversal of impairment		Reversal of impairment
Pemex Exploration and Production		Ps. (16,872,238	)		Ps. 288,581,670		Ps. 271,709,432
Pemex Industrial Transformation		(2,768,267	)		55,267,148		52,498,881
Pemex Logistics		—			5,829,520		5,829,520
Pemex Ethylene		—			1,276,510		1,276,510
Total		Ps. (19,640,505	)		Ps. 350,954,848		Ps. 331,314,343

Cash Generating Unit of Pemex Exploration and Production

Pemex Exploration and Production recognized a net reversal of impairment in the amount of Ps. 271,709,432 as of December 31, 2016, arising from (1) a reversal of Ps. 288,581,670 mainly due to the reallocation of resources towards oil fields with highest profitability and net cash flows arising from relatively greater efficiency in oil extraction and lower production costs, which fields are located primarily in the Aceite Terciario del Golfo, Crudo Ligero Marino, Burgos, Cantarell and Antonio J. Bermudez crude oil projects, (ii) the appreciation of the U.S. dollar against the Mexican peso by 20.1%, from a peso—U.S. dollar exchange rate of Ps. 17.2065 to U.S. $1.00 as of December 31, 2015 to a peso—U.S. dollar exchange rate of Ps. 20.6640 to U.S. $1.00 as of December 31, 2016, given that cash inflows are denominated in U.S. dollars and then translated to the reporting currency using the exchange rate at the end of the period, (iii) the change in the period used to estimate long-term prices of proved reserves and the recoverable amount of fixed assets from 20 years to 25 years in accordance with the amendment to the Lineamientos que regulan el procedimiento de cuantificación y certificación de reservas de la nación y el informe de los recursos contingentes relacionados (Guidelines regulating the quantification and certification procedures of the nation’s reserves and the related contingent resources report), (iv) the authorization, with respect to the assignments that are to be safeguarded for two years, to consider such assignments for an undetermined time until they are bidded and assigned to a contract and (v) the decrease in the discount rate; (2) an impairment of fixed assets of Ps. (16,872,238), mainly due to the fact that cash flows were not sufficient to cover the recovery value of the Lakach project as a result of the increase in investments in this strategic gas project.

The cash generating units of Pemex Exploration and Production are investment projects in productive fields with hydrocarbon reserves associated with proved reserves (1P). These productive hydrocarbon fields contain varying degrees of heating power consisting of a set of wells and are supported by fixed assets associated directly with production, such as pipelines, production facilities, offshore platforms, specialized equipment and machinery.

Each project represents the smallest unit which can concentrate the core revenues, with clear costs and expenses that enable future cash flows (value in use) to be determined.

To determine the value in use of long-lived assets associated to hydrocarbon extraction, the net present value of reserves is determined based on the following assumptions:

Average crude oil price	60.24 U.S. dollars/bl
Average gas price	4.69 U.S. dollars/mpc
Average condensates price	40.22 U.S. dollars/bl
Discount rate	14.36% annually

The total forecast production, calculated with a horizon of 25 years is 7,092 million bpce.

Pemex Exploration and Production determines the recoverable amount of fixed assets based on the long-term estimated prices for Pemex Exploration and Production’s proved reserves (1P). The recoverable amount on each asset is the value in use.

Cash Generating Unit of Pemex Industrial Transformation

As of December 31, 2016, Pemex Industrial Transformation recognized a net reversal of impairment of Ps. 52,498,881.

The net reversal of impairment was in the following cash generating units:

Minatitlán Refinery	Ps. 33,165,095
Madero Refinery	21,833,892
Arenque gas processor complex	268,161
Reversal of impairment	55,267,148
Cangrejera Petrochemical Center	(2,590,870	)
Independencia Petrochemical Center	(112,292	)
Matapionche gas processor complex	(65,105	)
Total impairment of assets	(2,768,267	)
Net reversal of impairment	Ps. 52,498,881

As of December 31, 2016, Pemex Industrial Transformation recognized a net reversal of impairment of Ps. 52,498,881 mainly due to (1) a reversal of impairment of Ps. 55,267,148 corresponding to the Madero and Minatitlán refineries due to higher prices than were forecasted in 2015 during the market decline, a decrease in the discount rate in the National Refinery System from 13.72% to 12.06%, and the appreciation of the U.S. dollar against the Mexican peso by 20.1%, from a peso—U.S. dollar exchange rate of Ps. 17.2065 to U.S. $1.00 as of December 31, 2015 to a peso—U.S. dollar exchange rate of Ps. 20.6640 to U.S. $1.00 as of December 31, 2016; (2) a reversal of impairment of the cash generating units of the Arenque gas processor complex of Ps. 268,161 due to an increase in the prices, the appreciation of the U.S. dollar against the Mexican peso and, improved efficiency in operating expenses and (3) impairment of three additional cash generating units, including Ps. (65,105) in the Matapionche gas processor complex, Ps. (2,590,870) in the Cangrejera Petrochemical Center and Ps. (112,292) for the Independencia Petrochemical Center, due to a decrease in the methanol price produced in these petrochemical centers.

Cash-generating units in Pemex Industrial Transformation are processing centers grouped according to their types of processes as refineries, gas complex processors, and petrochemical centers. These centers produce various finished products for direct sale to or intermediate products that can be processed in another of its cash generating units or by a third party.

Each processing center of Industrial Transformation represents the smallest unit which can concentrate the core revenues, with clear costs and expenses that enable future cash flows (value in use) to be determined.

Cash flows determination is made based on PEMEX’s business plans, operating financial programs, forecasts of future prices of products related to the processes of the cash generating units, budget programs and various statistical models that consider historical information of processes and the capacity of the various processing centers.

To determine the value in use of long-lived assets associated with the cash-generating units of Pemex Industrial Transformation, the net present value of cash flows was determined based on the following assumptions:

	Refining	Gas	Petrochemicals
Average crude oil price	52.30 U.S. dollars	N.A.	N.A.
Processed volume	1,100 mbd	3,085 mmpcd or sour gas	Variable because the load inputs are diverse
Rate of U.S. dollar	Ps.20.6640 mxp/usd	Ps.20.6640 mxp/usd	Ps.20.6640 mxp/usd
Useful lives of the cash generating units	Average of 14 years	Average of 10 years	Average of 4 years
Discount rate	12.06% annually	10.72% annually	10.29% annually
Period	2018-2034	2018-2029	2016-2024

The recoverable amount of assets is based on each asset’s value in use. The value in use for each asset is calculated based on cash flows, taking into consideration the volumes to be produced and sales to be carried out. As of December 31, 2017, the value in use for the impairment or reversal of impairment of fixed assets was as follows:

Minatitlán Refinery	Ps. 43,856,284
Madero Refinery	33,961,120
Salina Cruz Refinery	36,057,410
Cangrejera Petrochemical Center	2,441,686
Independencia Petrochemical Center	1,706,687
Arenque gas processor complex	473,499
Matapionche gas processor complex	572,909
Total value in use	Ps. 119,069,595

Cash generating unit of logistics

The cash generating units of PEMEX’s logistics segments are pipelines, tankers, storage terminals and transportation equipment used for service, transport and storage of oil, oil products and petrochemicals.

Pemex Logistics calculates the recoverable amount of assets based on the value in use. The value in use for each asset is calculated based on cash flows, taking into consideration services income. As of December 31, 2016, the value in use amounted to Ps. 139,436,715. Until December 31, 2016, the projection of cash flows was calculated based on a period of 5 years. During 2016 the discount rate used was 12.63%.

As of December 31, 2016, reversal of impairment amounted Ps. 5,829,520, mainly due to improvements in operating costs.

Cash generating unit of ethylene

Pemex Ethylene calculates the recoverable amount of assets based on the value in use. The value in use for each asset is calculated based on cash flows, taking into consideration services income. As of December 31, 2016 reversal of impairment amounted to Ps.1,276,510. During 2016 the discount rate used was 10.29%.

f. PEMEX entered into certain capital lease arrangements for tankers. These leases expire on various dates until 2018.

As of December 31, 2013, PEMEX had entered into nine capital lease arrangements for drilling equipment. These leases expire on various dates over the next 10 years.

As of December 31, 2015, PEMEX had entered into certain capital lease arrangements for two offshore platforms. These leases expire on various dates over the next 10 years.

As of December 31, 2017 and 2016, assets acquired through these capital leases were as follows:

	2017			2016
Investment in tankers and drilling equipment	Ps.	11,142,197		Ps.	11,142,197
Less accumulated depreciation		(1,696,089	)		(1,274,314	)
	Ps.	9,446,108		Ps.	9,867,883

The liabilities relating to the assets listed above are payable in the years following December 31, 2017 as presented below:

Year	Pesos		U.S. dollars
2018		Ps. 1,867,411		94,377
2019		1,192,496		60,268
2020		1,192,496		60,268
2021		1,192,496		60,268
2022		1,192,496		60,268
2023 and thereafter		2,158,559		109,091
		8,795,954		444,540
Less: short-term unaccrued interest		331,412		16,749
Less: long-term unaccrued interest		843,480		42,630
Total capital leases		7,621,062		385,161
Less: current portion of leases (excluding interest)		1,543,881		78,026
Total long-term capital leases		Ps. 6,077,181	U.S. $	307,135

The interest expense from capital leases for the years ended December 31, 2017, 2016 and 2015 was Ps. 418,883, Ps. 500,654 and Ps. 450,760, respectively.

The discount rates applied to the calculation of capital leases were as follows:

i. 7.96 % rate in nominal terms (1.11% in real terms) as of December 31, 2017.

ii. 7.96 % rate in nominal terms (4.45% in real terms) as of December 31, 2016.

iii. 7.96 % rate in nominal terms (5.71% in real terms) as of December 31, 2015.

g. Certain infrastructure assets used for oil and gas activities are guarantees for the U.S. $1,100,000 and U.S. $600,000 sale and lease back agreements dated as of June 17, 2016 and July 8, 2016 (see Note 15).

h. PEMEX can conduct exploration and extraction activities through Exploration and Extraction Contracts (EEC). The EECs are awarded individually, through associations or joint ventures based on guidelines approved by the NHC and are classified into:

a. Production-sharing contracts;

b. Profit-sharing contracts;

c. License agreements; and

d. Service contracts.

Certain of the EECs are operated though joint arrangements, for which PEMEX recognizes in its financial statements, both the rights to the assets and the obligations for the liabilities, as well as profits and losses relating to the arrangements.

EECs as of December 31, 2017 are:

a. Production-sharing contracts

i. Hydrocarbon Extraction Contract (Shallow Water), Ek-Balam contractual area.

The object of the contract is the execution of oil activities, under shared production contracts, between, Mexico through the Mexican Government via the NHC and Pemex Exploration and Production, as a contractor, for the contractual area and all the costs, risks, terms and conditions involved in the contract and in accordance with the applicable regulations and best practices of the Industry receiving, in exchange, benefits in favor of the contractor.

Pemex Exploration and Production got the 100% of this contractual area.

ii. Exploration and Extraction Contract related to Area 2 Tampico Misantla, with the association formed by Pemex Exploration and Production and DEA.

The object of the contract is the realization of oil activities, under shared production contracts, by the contractor for the contractual area and all the costs, risks, terms and conditions involved in the contract and in accordance with the applicable regulations and best practices of the Industry receiving, in exchange, benefits in favor of the contractor.

Pemex Exploration and Production owns 70% of this contractual area, while DEA has the 30% of this contractual area, respectively. The condition of operator will be in charge of Pemex Exploration and Production.

This contract requires a total investment of U.S. $ 45,230 million, of which U.S. $ 36,520 million correspond to exploratory activities to be carried out in the period of 2017-2021.

iii. Exploration and Extraction Contract, related to Area 8 Cuencas del Sureste, pursuant to consortium formed by Pemex Exploration and Production and EPC Hidrocarburos México, S. A. de C. V. company (EPC).

Pemex Exploration and Production was designated by all the participating companies and with the approval of the NHC as the operator of this contract and all operational aspects of the petroleum activities will be carried out only by the operator on behalf of all participating companies.

Pemex Exploration and Production and EPC each have a 50% interest in this contractual area.

b. License contracts

i. A licensing contract with BHP Billiton Petróleo Operaciones de México, S. de R.L. (BHP Billiton) for the Trión block, under which BHP Billiton has the right to explore and extract hydrocarbons owned by Mexico in the contractual area and bears the costs and risks associated with such exploration and extraction activities.

BHP Billiton owns 60% of the contractual area, while Pemex Exploration and Production owns 40%.

ii. Hydrocarbons Exploration and Extraction Contract for the contractual area 3 “Plegado Perdido”, in deep waters, formed by Inpex, Chevron and Pemex Exploration and Production.

A licensing contract that permits the exploration and extraction of hydrocarbons owned by Mexico in the contractual area. Chevron was appointed by the participating companies, with the approval of the NHC, as the operator of this contract on behalf of each of the participating companies.

Chevron, Pemex Exploration and Production and Inpex have a 33.3334%, 33.3333% and 33.3333% interest in this project, respectively.

See below for a condensed statement of comprehensive income and condensed statement of financial position, summarizing the projects listed above:

	Profit-sharing								License
As of /For the year ended December 31, 2017	EK / Balam		Block 2			Block 8			Trion		Block 3			Total
Sales:
Net sales	Ps.	7,009,464	Ps.	—		Ps.	—		Ps.	—	Ps.	—		Ps.	7,009,464
Cost of sales		5,447,955		5,953			4,845			—		511			5,459,264
Gross income (loss)		1,561,509		(5,953	)		(4,845	)		—		(511	)		1,550,200
Other income (loss), net		4,852		—			—			—		—			4,852
Administrative expenses		34,338		—			—			—		—			34,338
Operating income (loss)		1,532,023		(5,953	)		(4,845	)		—		(511	)		1,520,714
Taxes, duties and other		158,347		—			—			—		—			158,347
Net income (loss)	Ps.	1,373,676	Ps.	(5,953	)	Ps.	(4,845	)	Ps.	—	Ps.	(511	)	Ps.	1,362,367
Cash and cash equivalents	Ps.	—	Ps.	20		Ps.	25		Ps.	—	Ps.	—		Ps.	45
Accounts receivable		—		1,013			1,804			—		327			3,144
Total current assets		—		1,033			1,829			—		327			3,189
Wells, pipelines, properties, plant and equipment, net		14,869,906		—			—			4,498,234		1,107,311			20,475,451
Total assets		14,869,906		1,033			1,829			4,498,234		1,107,638			20,478,640
Suppliers		796,300		—			—			—		—			796,300
Taxes and duties payable		973		—			—			—		—			973
Other current liabilities		4,391		1,809			2,369			—		—			8,569
Total current liabilities		801,664		1,809			2,369			—		—			805,842
Total liabilities	Ps.	801,664	Ps.	1,809		Ps.	2,369		Ps.	—	Ps.	—		Ps.	805,842
Equity (deficit), net	Ps.	14,068,242	Ps.	(776	)	Ps.	(540	)	Ps.	4,498,234	Ps.	1,107,638		Ps.	19,672,798

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Intangible Assets

12 Months Ended

Dec. 31, 2017

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Intangible Assets

NOTE 13. INTANGIBLE ASSETS

At December 31, 2017 and 2016, intangible assets are wells unassigned to a reserve, which amounted Ps. 9,088,563 and Ps. 8,639,242, respectively as follows:

	2017			2016
Wells unassigned to a reserve:
Balance at the beginning of period	Ps.	8,639,242		Ps.	14,304,961
Additions to construction in progress		20,553,952			20,526,300
Transfers against expenses		(3,663,986	)		(9,798,246	)
Transfers against fixed assets		(16,440,645	)		(16,393,773	)
Balance at the end of period	Ps.	9,088,563		Ps.	8,639,242

In addition, as of December 31, 2017 and 2016, PEMEX recognized expenses related to unsuccessful wells of Ps. 2,500,638 and Ps. 19,307,838, respectively, directly in its statement of comprehensive income.

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Long-Term Notes Receivable and Other Assets

12 Months Ended

Dec. 31, 2017

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Long-Term Notes Receivable and Other Assets

NOTE 14. LONG-TERM NOTES RECEIVABLE AND OTHER ASSETS

a. Long-term notes receivable

As of December 31, 2017 and 2016, the balance of long-term notes receivable was as follows:

	2017		2016
Promissory notes issued by the Mexican Government	Ps	. 147,274,076	Ps	.140,578,871
Other long-term notes receivable(1)		1,218,833		8,028,731
Total long-term notes receivable	Ps	. 148,492,909	Ps	.148,607,602

(1) For 2016, primarily CENAGAS.

Promissory notes issued by the Mexican Government

	2017		2016
Total promissory notes	Ps	.149,796,282	Ps	.142,124,620
Less: current portion of notes receivable(1)		2,522,206		1,545,749
Long-term promissory notes	Ps	.147,274,076	Ps	.140,578,871

(1) The current portion of the promissory notes and the total yield payments are allocated under sundry debtors in accounts receivable, net (see Note 7).

On December 24, 2015, the SHCP published in the Official Gazette of the Federation the Disposiciones de carácter general relativas a la asunción por parte del Gobierno Federal de obligaciones de pago de pensiones y jubilaciones a cargo de Petróleos Mexicanos y sus empresas productivas subsidiarias (General provisions regarding the assumption by the Mexican Government of the payment obligations related to pensions and retirement plans of Petróleos Mexicanos and its productive state-owned subsidiaries). These regulations stated the terms, conditions, financing mechanisms and payment arrangements pursuant to which the SHCP would assume a portion of the payment obligations related to PEMEX’s pensions and retirement plans. An independent expert reviewed the calculation, the methodology used, the maturity profile and all of the information provided by PEMEX.

In accordance with these provisions and prior to the completion of the independent expert’s review described above, on December 24, 2015, the Mexican Government issued in advance payment, through the SHCP, a Ps. 50,000,000 non-negotiable promissory note due December 31, 2050 payable to Petróleos Mexicanos. The promissory note, which accrued interest at a rate of 6.93% per year, was recognized as a long-term note receivable in non-current assets once the independent expert named by SHCP concluded its review.

On August 5, 2016, Petróleos Mexicanos received promissory notes issued by the Mexican Government at a value of Ps. 184,230,586 as of June 29, 2016, as part of the Mexican Government’s assumption of a portion of the payment liabilities related to Petróleos Mexicanos and Subsidiary Entities’ pensions and retirement plans, which notes were delivered in exchange for the Ps. 50,000,000 promissory notes issued to Petróleos Mexicanos on December 24, 2015. On August 15, 2016, Petróleos Mexicanos exchanged Ps. 47,000,000 of these promissory notes for short-term floating rate Mexican Government debt securities, known as Bonos de Desarrollo del Gobierno Federal (Development Bonds of the Mexican Government or “BONDES D”). Petróleos Mexicanos then sold the BONDES D to Mexican development banks at market prices.

Petróleos Mexicanos recognized a Ps. 135,439,612 increase in equity as a result of the Ps. 184, 230,586 of the promissory notes as of June 29, 2016, minus the Ps. 50,000,000 promissory note received by Petróleos Mexicanos on December 24, 2015, plus a Ps. 1,209,026 increase in the value of the promissory notes from June 29, 2016 to August 15, 2016, the date on which PEMEX received the promissory notes (see Note 21).

As of December 31, 2017 and 2016, these promissory notes amounted to Ps. 147,274,076 and Ps. 140,578,871, respectively. PEMEX intends is to hold them to maturity. These promissory notes will be converted into cash with annual maturity dates ranging from 2018 to 2042 and annual rates ranging from 4.65% to 7.03% with annual maturity dates in 2017 and ranging from 2017 to 2042 and annual rates ranging from 4.35% to 7.04% in 2016, as follows:

As of December 31, 2017
Number of Promissory Notes	Maturity	Yield Rate Range	Principal Amount
1	2018	4.65%	Ps.	2,522,206
1	2019	5.14%		3,580,302
1	2020	5.39%		4,421,320
1	2021	5.57%		5,238,081
1	2022	5.74%		5,804,485
5	2023 to 2027	5.87% to 6.32%		34,196,434
5	2028 to 2032	6.47% to 6.81%		35,338,617
5	2033 to 2037	6.85% to 7.03%		32,789,697
5	2038 to 2042	7.02% to 6.94%		25,905,140
	Total promissory notes			149,796,282
	Less: current portion		Ps.	2,522,206
	Long-term notes receivable		Ps.	147,274,076

As of December 31, 2016
Number of Promissory Notes	Maturity	Yield Rate Range	Principal Amount
1	2017	4.35%	Ps.	1,545,749
1	2018	4.65%		2,408,634
1	2019	5.14%		3,402,849
1	2020	5.39%		4,192,132
1	2021	5.57%		4,957,840
5	2022 to 2026	4.74% a 6.11%		30,986,252
5	2027 to 2031	6.32% a 6.77%		33,280,216
5	2032 to 2036	6.81% a 7.00%		31,370,504
6	2037 to 2042	6.94% a 7.04%		29,980,444
	Total promissory notes		Ps.	142,124,620
	Less: current portion			1,545,749
	Long-term notes receivable		Ps.	140,578,871

During 2017 and 2016, PEMEX received Ps. 9,233,950 and Ps. 3,597,654, respectively, in accrued yields from these promissory notes, which was recognized as financing income in the consolidated statement of comprehensive income.

Yield rates for these promissory notes are pre-determined and fixed all throughout their lifespans and up to their maturities. Accordingly, fixed rates may not reflect market interest rate conditions as of the due date of each promissory note. In addition, PEMEX believes the promissory notes do not have a credit risk because they are issued by the Mexican Government in Mexican pesos.

As of December 31, 2017, the remaining Ps. 22,217,300 corresponding to Ps. 47,000,000 of the Mexican Government contribution was transferred to the Fondo Laboral PEMEX (Pemex Labour Trust or “FOLAPE”), for the period from January 2017 to June 2017 in accordance with the authorized expenditure budget framework for the fiscal year 2017.

In addition, the promissory note maturing in 2017 was contributed to the FOLAPE in June 2017 in the amount of Ps. 1,562,288.

b. Other assets

At December 31, 2017 and 2016, the balance of other assets was as follows:

	2017		2016
Payments in advance	Ps.	4,683,117	Ps.	2,558,767
License		2,162,151		1,813,605
Rights-of-way		1,967,304		1,940,157
Other		2,672,605		3,200,116
Total other assets	Ps.	11,485,177	Ps.	9,512,645

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Debt

12 Months Ended

Dec. 31, 2017

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Debt

NOTE 15. DEBT

The Federal Income Law applicable to PEMEX as of January 1, 2017, published in the Official Gazette of the Federation on November 17, 2016, authorized Petróleos Mexicanos and its Subsidiary Entities to incur an internal net debt up to Ps. 28,000,000 and an external net debt up to U.S. $7,100,000. PEMEX can incur additional internal or external debt, as long as the total amount of net debt (Ps. 150,000,000 equivalent to U.S. $8,055,900) does not exceed the ceiling established by the Federal Income Law.

On July 8, 2016, the Board of Directors of Petróleos Mexicanos approved policies and general requirements for obligations that constitute public debt of Petróleos Mexicanos and Subsidiary Entities, in accordance with Article 106 section I of the Petroleos Mexicanos Law.

Subsequently, the Board of Directors of PEMEX, approved the debt program for fiscal year 2017 in accordance with Article 13 section XXVI of the Petróleos Mexicanos Law.

During the period from January 1 to December 31, 2017, PEMEX participated in the following financing activities:

a. On February 14, 2017, Petróleos Mexicanos issued € 4,250,000 of debt securities under its Medium-Term Notes Program, Series C in three tranches: (i) € 1,750,000 of its 2.50% Notes due August 2021;(ii) € 1,250,000 of its 3.75% Notes due February 2024; and (iii) € 1,250,000 of its 4.875% Notes due February 2028.

b. On April 6, 2017, Petróleos Mexicanos executed a U.S. $132,000, non-revolving bilateral credit line from Banco Mercantil del Norte, S.A., Institución de Banca Múltiple, Grupo Financiero Banorte, due on April 6, 2024, which bears a fixed interest rate of 5.25%.

c. On May 15, 2017, Petróleos Mexicanos entered into a simple credit line in the amount of U.S. $400,000 at a floating interest rate linked to LIBOR plus 165 basis points, due May 2020 and was used in two tranches of U.S. $200,000 (on May 24, 2017 and July 14, 2017, respectively).

d. On June 16, 2017, Petróleos Mexicanos increased its Medium-Term Notes Program, Series C, from U.S. $72,000,000 to U.S. $92,000,000.

e. On July 17, 2017, Petróleos Mexicanos entered into a revolving credit facility in the amount of U.S. $1,950,000 and matures in 2020.

f. On July 18, 2017, Petróleos Mexicanos issued under its U.S.$92,000,000 Medium-Term Notes Program, Series C: (i) U.S. $2,500,000 of its 6.500% Notes due 2027; and (ii) U.S. $2,500,000 of its 6.75% Bonds due 2047.

g. On July 21, 2017, Petróleos Mexicanos consummated a tender offer pursuant to which it purchased U.S. $922,485 aggregate principal amount of its outstanding 5.750% Notes due 2018, U.S. $644,374 aggregate principal amount of its outstanding 3.500% Notes due 2018 and U.S. $172,591 aggregate principal amount of its outstanding 3.125% Notes due 2019.

h. On November 16, 2017, Petróleos Mexicanos issued £ 450,000 at a rate interest of its 3.750% Notes due 2025 under its U.S.$92,000,000 Medium-Term Notes Program, Series C.

i. On December 15, 2017, AGRO refinanced a credit line for U.S. $390,000, prepaying U.S. $140,000 and entering into a new credit line for the outstanding U.S. $250,000, which bears interest at a floating rate linked to LIBOR plus 250 basis points on a quarterly basis and matures on June 29, 2018.

j. On December 18, 2017, Petróleos Mexicanos entered into a bilateral credit line facility in the amount of U.S. $200,000, which bears interest at a floating rate linked to LIBOR plus 165 basis points and matures on December 18, 2020.

k. On December 21, 2017, Petróleos Mexicanos borrowed U.S. $300,000 from a bilateral credit line which bears interest at a floating rate linked to LIBOR plus 175 basis points, which matures on December 21, 2022.

All the financing activities were guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

From January 1 to December 31, 2017, PMI HBV obtained U.S. $15,141,500 in financing from its revolving credit line and repaid U.S. $14,914,000. As of December 31, 2017, the outstanding amount under this revolving credit line was U.S. $227,500.

As of December 31, 2017, Petróleos Mexicanos had U.S. $6,700,000 and Ps. 23,500,000 in available credit lines in order to ensure liquidity. The available amounts are U.S. $5,400,000 and Ps. 23,500,000, respectively.

The Federal Income Law that was applicable to PEMEX as of January 1, 2016, published in the Official Gazette of the Federation on November 18, 2015, authorized Petróleos Mexicanos and its Subsidiary Entities to incur an internal net debt up to Ps. 110,500,000 and an external net debt up to U.S. $8,500,000. PEMEX was entitled to incur additional internal or external debt, as long as the total amount of net debt (Ps.240,550,000 equivalent to U.S. $15,722,000) did not exceed the ceiling established by the Federal Income Law.

On November 18, 2014, the Board of Directors of Petróleos Mexicanos approved policies and general requirements for obligations that constitute public debt of Petróleos Mexicanos and Subsidiary Entities, in accordance with the Article 107 of the Petroleos Mexicanos Law.

Subsequently, the Board of Directors of PEMEX, approved the debt program for fiscal year 2016 in accordance with Article 13 section XXVI of the Petróleos Mexicanos Law.

During 2016, PEMEX participated in the following financing activities:

a. On January 25, 2016, Petróleos Mexicanos increased its Medium-Term Notes Program from U.S. $52,000,000 to U.S. $62,000,000.

b. On February 4, 2016, Petróleos Mexicanos issued U.S. $5,000,000 of debt securities under its Medium-Term Notes Program, Series C, in three tranches: (i) U.S. $750,000 of its 5.500% Notes due February 2019; (ii) U.S. $1,250,000 of its 6.375% Notes due February 2021; and (iii) U.S. $3,000,000 of its 6.875% Notes due August 2026. All debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

c. On February 5, 2016, Petróleos Mexicanos obtained a loan from a line of credit for Ps. 7,000,000,000 bearing interest at a floating rate linked to the TIIE, plus 0.55%, and matured on January 2017.

d. On March 15, 2016, Petróleos Mexicanos issued €2,250,000 of debt securities U.S. $62,000,000 Medium-Term Notes Program, Series C in two tranches: (i) €1,350,000 of its 3.750% Notes due to March 2019 and (ii) €900,000 of its 5.125% Notes due to March 2023. All debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

e. On March 17, 2016, Petróleos Mexicanos borrowed Ps. 2,000,000 from a credit line at a floating rate linked to TIIE and matured on March 2017.

f. On March 17, 2016, Petróleos Mexicanos borrowed Ps. 3,300,000 from a credit line at a floating rate linked to TIIE and matured on March 2017.

g. On March 23, 2016, Petróleos Mexicanos issued Ps. 5,000,000 of Certificados Bursátiles due to October 2019 at a floating rate linked to TIIE. As of December 31, 2016, all debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

h. On March 28, 2016, Petróleos Mexicanos borrowed Ps. 9,700,000 from a credit line at a floating rate linked to TIIE, and matured on March 2017.

i. On April 19, 2016, Petróleos Mexicanos borrowed €500,000 from a credit line at fixed rate of 5.11%, which matures on March 2023.

j. On May 31, 2016, Petróleos Mexicanos obtained a U.S. $300,000 bilateral credit line from Export Development Canada (EDC), due on May 2021, which bears interest at a floating rate linked to LIBOR.

k. On June 14, 2016, Petróleos Mexicanos issued CHF 375,000 of debt securities under its Medium-Term Notes Program, Series C, in two tranches: (1) CHF 225,000 of its 1.50% Notes due to June 2018 and (2) CHF 150,000 of its 2.35% Notes due to December 2021. The Notes are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

l. On June 17, 2016, Pemex Exploration and Production obtained approximately U.S. $1,100,000 in connection with the sale and leaseback of certain infrastructure assets used for oil and gas activities (see Note 12-g). As part of this transaction, Pemex Exploration and Production entered into a 15-year financial lease agreement, which will last for the greater part of the economic life of the asset, at a fixed rate of 8.38%, pursuant to which Pemex Exploration and Production will retain the operation of these assets and the title and ownership of such assets will revert to Pemex Exploration and Production at the end of this period following payment of an agreed price. This transaction was recognized as a financing activity due to the fact that PEMEX retained all of the risks and benefits associated with ownership of the asset and substantially all of the operating rights of the asset.

m. On July 8, 2016, Pemex Industrial Transformation obtained approximately U.S. $600,000 in connection with the sale and leaseback of a plant located in the Madero Refinery. As part of this transaction, Pemex Industrial Transformation entered into a 20-year financial lease agreement pursuant to which Pemex Industrial Transformation will retain the operation of the plant and title and ownership will revert to Pemex Industrial Transformation at the end of this period following payment of an agreed price. This transaction was recognized as a financing activity due to the fact that Pemex Industrial Transformation retained all of the risks and benefits associated with ownership of the asset and substantially all of the operating rights of the asset.

n. On July 26, 2016, Petróleos Mexicanos issued ¥80,000,000 Bonds at 0.54% due July 2026. The Bonds are guaranteed by the Japan Bank for International Cooperation.

o. On September 21, 2016, Petróleos Mexicanos issued U.S. $4,000,000 aggregate principal amount of debt securities under its U.S. $62,000,000 Medium-Term Notes Program, Series C, in two tranches: (i) U.S. $2,000,000 of its 4.625% Notes due to September 2023 and (ii) U.S. $2,000,000 of its 6.750% Bonds due to September 2047. The debt securities are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

p. On October 3, 2016, Petróleos Mexicanos consummated a tender and exchange offer pursuant to which it (i) purchased U.S. $687,725 aggregate principal amount of its outstanding 8.000% Notes due 2019 and U.S. $657,050 aggregate principal amount of its outstanding 5.750% Notes due 2018 and (ii) exchanged (a) U.S. $73,288 aggregate principal amount of its outstanding 5.750% Notes due 2018 for U.S. $69,302 aggregate principal amount of its 4.625% Notes due 2023 and U.S. $8,059 aggregate principal amount of its 6.750% Bonds due 2047 and (b) U.S. $1,591,961 aggregate principal amount of its outstanding 5.500% Bonds due 2044 for U.S. $1,491,941 aggregate principal amount of its 6.750% Bonds due 2047. The 4.625% Notes due 2023 and 6.750% Bonds due 2047 are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services and represent reopenings of the 4.625% Notes due 2023 and 6.750% Bonds due 2047, respectively, originally issued on September 21, 2016

q. On December 6, 2016, Petróleos Mexicanos increased its Medium-Term Notes Program, Series C, from U.S. $ 62,000,000 to U.S. $72,000,000.

r. On December 13, 2016, Petróleos Mexicanos issued U.S. $5,500,000 of its debt securities under its Medium-Term Notes Program, Series C in three tranches: (1) U.S. $3,000,000 at fixed rate of 6.50% due March 2027, (2) U.S. $1,500,000 a fixed rate of 5.375% due March 2022, and (3) U.S. $1,000,000 at a floating rate linked to LIBOR, due March 2022. As of December 31, 2016, all debt securities issued under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

s. On December 14, 2016, Petróleos Mexicanos entered into a term loan credit facility in the amount of U.S. $300,000 at floating rate linked to LIBOR, matures on December 2019.

Between January 1 and December 31, 2016, PMI HBV obtained and paid U.S. $11,369,800 in revolving credit lines. As of December 31, 2016 there was no outstanding amount.

As of December 31, 2016, Petróleos Mexicanos had U.S. $4,750,000 and Ps. 23,500,000 in available credit lines in order to ensure liquidity. The available amounts are U.S. $4,630,000 and Ps. 3,500,000, respectively.

Various financial transactions (including credit facilities and bond issuances) require compliance with various covenants that, among other things, place restrictions on the following types of transactions by PEMEX, subject to certain exceptions:

• The sale of substantial assets essential for the continued operations of its business.

• The incurrence of liens against its assets.

• Transfers, sales or assignments of rights to payment not yet earned under contracts for the sale of crude oil or natural gas, accounts receivable or other negotiable instruments.

As of December 31, 2017 and as of the date of the issuance of these consolidated financial statements, PEMEX was in compliance with the covenants described above.

As of December 31, 2017, long-term debt was as follows:

				Pesos		Foreign currency
	Rate of interest(1)	Maturity		(thousands)		(thousands)
U.S. dollars
Bonds	Fixed from 1.7% to 9.5% and LIBOR plus 0.35% to 3.65%		Various to 2047		Ps. 1,138,845,231	US$	57,556,097
Purchasing loans	LIBOR plus 0.85%		Various to 2018		25,722,710		1,300,000
Project financing	Fixed from 2.35% to 3.81% and LIBOR plus 0.24% to 1.75%		Various to 2025		64,974,389		3,283,741
Direct loans	Fixed from 5.25% to 5.44% and LIBOR plus 1.65%		Various to 2020		43,141,231		2,180,315
Syndicated loans	LIBOR plus 0.85%		Various to 2020		39,347,774		1,988,597
Bank loans	Fixed from 3.5% to 5.28%		Various to 2023		3,451,629		174,442
Financial leases	Fixed from 0.38% to 1.99%		Various to 2025		7,621,062		385,161
Lease-back (See Financing activities for 2016 l) and m))(4)	Fixed from 0.45% to 0.7%		Various to 2036		32,677,268		1,651,476
Total financing in U.S. dollars					1,355,781,294	US$	68,519,829
Euros
Bonds	Fixed from 1.875% to 5.5%		Various to 2030		287,386,195	€	12,097,975
Project financing	Fixed from 2.1% to 5.11%		Various to 2023		11,879,379		500,081
Total financing in Euros					299,265,574	€	12,598,056
Japanese yen:
Bonds	Fixed from 0.54% to 3.5% and LIBOR yen plus 0.75%		Various to 2026		30,541,407	¥	173,827,018
Pesos
Certificados bursátiles	Mexican Government Treasury Certificates (“Cetes”) , TIIE(1) less 0.06% to 1.35%, and fixed at 7.19% to 9.1%		Various to 2026		Ps. 149,564,918
Direct loans	Fixed at 6.55% and TIIE plus 0.85% to 1.25%		Various to 2025		28,597,423
Syndicated loans	TIIE plus 0.95		Various to 2025		33,646,107
Total financing in pesos					Ps. 211,808,448
Unidades de Inversión Certificados bursátiles
Certificados bursátiles	Zero rate and Fixed at 3.02% to 5.23%		Various to 2035		57,197,211
Other currencies:
Bonds	Fixed from 1.5% to 8.25%		Various to 2025		47,148,936
Total principal in pesos(2)					2,001,742,870
Plus: accrued interest					32,078,624
Notes payable to contractors(3)					4,053,577
Total principal and interest					2,037,875,071
Less: short-term maturities					122,957,558
Current portion of notes payable to contractors(3)					2,173,285
Accrued interest					32,078,624
Total short-term debt and current portion of long-term debt					157,209,467
Long-term debt (Note 16(c))					Ps. 1,880,665,604

As of December 31, 2016, long-term debt was as follows:

	Rate of interest(1)	Maturity	Pesos (thousands)		Foreign currency (thousands)
U.S. dollars
Bonds	Fixed from 3.125% to 9.5% and LIBOR plus 0.35% to 2.02%	Various to 2046		Ps. 1,131,389,914	U.S. $	54,751,738
Purchasing loans	LIBOR plus 0.8% to 0.85%	Various to 2016		2,479,680		120,000
Project financing	Fixed from 2.35% to 5.45% and LIBOR plus 0.01% to 1.71%	Various to 2021		84,711,684		4,099,481
Direct loans	Fixed at 5.44% and LIBOR plus 1.0%	Various to 2018		33,100,587		1,601,848
Syndicated loans	LIBOR plus 0.85%	Various to 2020		41,056,571		1,986,865
Bank loans	Fixed from 3.5% to 5.28%	Various to 2023		4,339,826		210,019
Financial leases	Fixed from 0.38% to 1.99%	Various to 2025		9,559,060		462,595
Lease-back (See Financing activities for 2016 l) and m))(4)	Fixed from 0.45% to 0.7%	Various to 2036		35,513,114		1,718,598
Total financing in U.S. dollars				1,342,150,436	U.S. $	64,951,144
Euros
Bonds	Fixed from 3.125% to 6.375%	Various to 2030		196,317,016	€	9,058,388
Project financing	Fixed at 2%	Various to 2016		10,836,200		500,000
Total financing in Euros				207,153,216	€	9,558,388
Japanese yen:
Bonds	Fixed at 3.5% and LIBOR yen plus 0.75%	Various to 2023		30,800,746	¥	173,809,300
Project financing	Fixed at 1.56% and Prime Rate yen plus 2.56%	Various to 2017		517,286		2,919,056
Total financing in yen				31,318,032	¥	176,728,356
Pesos
Certificados bursátiles	Mexican Government Treasury Certificates (“Cetes”) , TIIE(1) less 0.06% to 0.35%, and fixed at 7.19% to 9.15%	Various to 2026	Ps.	173,151,985
Direct loans	Fixed at 6.55% and TIIE plus 0.55% to 1.25%	Various to 2025		45,563,848
Syndicated loans	TIIE plus 0.95	Various to 2025		38,538,961
Revolved loans	TIIE plus 0.55	To 2016		20,000,000
Total financing in pesos			Ps.	277,254,794
Unidades de Inversión Certificados bursátiles
Certificados bursátiles	Zero rate and Fixed at 3.02% to 5.23%	Various to 2035		53,703,421
Other currencies:
Bonds	Fixed from 2.5% to 8.25%	Various to 2022		36,786,665
Total principal in pesos(2)				1,948,366,564
Plus: accrued interest				27,815,467
Notes payable to contractors(3)				6,988,699
Total principal and interest				1,983,170,730
Less: short-term maturities				144,169,619
Current portion of notes payable to contractors(3)				4,181,102
Accrued interest				27,815,467
Total short-term debt and current portion of long-term debt				176,166,188
Long-term debt (Note 16(c))			Ps.	1,807,004,542

(1) As of December 31, 2017 and 2016, interest rates were as follows: 3 month LIBOR of 1.69428% and 0.99789%, respectively; 6 month LIBOR of 1.83707% and 1.31767%, respectively; TIIE rate of 7.6241% and 6.1066%, respectively, for 28 days; TIIE rate of 7.6556% and 6.1875%, respectively, for 91 days; Cetes rate of 7.22% and 5.69%, respectively, for 28 days; Cetes rate of 7.36% and 5.96%, respectively, for 91 days; Cetes rate of 7.53% and 6.09%, respectively, for 182 days.

(2) Includes financing from foreign banks of Ps. 1,701,363,406 and Ps. 1,600,968,832, as of December 31, 2017 and 2016, respectively.

(3) The total amounts of notes payable to contractors as of December 31, 2017 and 2016, current and long-term, are as follows:

	2017		2016
Total notes payable to contractors(a)(b)		Ps.4,053,577		Ps.6,988,699
Less: current portion of notes payable to contractors		2,173,285		4,181,102
Notes payable to contractors (long-term)		Ps.1,880,292		Ps.2,807,597

(a) PEMEX has entered into FPWCs pursuant to which the hydrocarbons and construction in progress are property of Pemex Exploration and Production. Pursuant to the FPWC, the contractors manage the work in progress, classified as development, infrastructure and maintenance. As of December 31, 2017 and 2016, PEMEX had an outstanding amount payable of Ps. 1,678,843 and Ps. 3,986,565, respectively.

(b) During 2007, Pemex-Exploration and Production contracted for the purchase of a Floating Production Storage and Offloading (“FPSO”) vessel. The investment in the vessel totaled U.S. $723,575. As of December 31, 2017 and 2016, the outstanding balances owed to the contractor were Ps. 2,374,734 (U.S. $120,017) and Ps. 3,002,134 (U.S. $145,283), respectively. In accordance with the contract, the estimated future payments are as follows:

Year	Amount
2018	U.S.$	25,267
2019		25,267
2020		25,267
2021		25,267
2022		18,949
Total	U.S $	120,017

(4) PEMEX obtained financing through the sale and leaseback of certain infrastructure assets and a plant, which will require periodic payments through 2036.

This transaction was recognized as a financing activity due to the fact that PEMEX retained all of the risks and benefits associated with ownership of the asset and substantially all of the operating rights to the assets.

The outstanding liability for this transaction is payable as follows:

Years	Pesos		U.S. dollars
2018		Ps. 3,957,317	U.S. $	199,999
2019		3,886,037		196,396
2020		3,886,037		196,396
2021		3,886,037		196,396
2022		3,886,037		196,396
2023 and thereafter		39,450,325		1,993,781
		58,951,790		2,979,364
Less: short-term unaccrued interest		2,399,475		121,267
Less: long-term unaccrued interest		23,875,047		1,206,621
Total financing		32,677,268		1,651,476
Less: short-term portion of financing (excluding interest)		1,557,842		78,732
Total long term financing		Ps. 31,119,426	U.S.$	1,572,744

(5) As of December 31, 2017 and 2016, PEMEX used the following exchange rates to translate the outstanding balances in foreign currencies to pesos in the statement of financial position:

	2017		2016
U.S. dollar		Ps. 19.7867		Ps. 20.6640
Japanese yen		0.1757		0.1772
Pounds sterling		26.7724		25.3051
Euro		23.7549		21.6724
Swiss francs		20.2992		20.1974
Canadian dollar		15.7858		15.2896
Australian dollar		15.4752		14.8842

2018

2019

2020

2021

2022

2023 and thereafter

Total

Maturity of the total principal outstanding and accrued interest as of December 31, 2017, for each of the years ending December 31.

Ps.157,209,467

Ps.159,403,397

Ps,209,915,748

Ps.185,307,669

Ps.158,761,145

Ps.1,167,277,645

Ps.2,037,875,071

The following table presents the roll-forward of total debt of PEMEX for each of the year ended December 31, 2017 and 2016, which includes short and long-term debt:

	2017(i)			2016(i)
Changes in total debt:
At the beginning of the year		Ps.1,983,170,730			Ps.1,493,381,835
Cash flows:
Loans obtained—financing institutions		704,715,468			829,579,084
Loans obtained—financing lease		—			21,924,053
Debt payments		(642,059,819	)		(614,987,329	)
Interest paid		(108,910,417	)		(88,757,428	)
Non-cash flows:
Foreign exchange		(16,685,439	)		243,182,764
Accrued interest		117,644,548			98,847,751
At the end of the year		Ps.2,037,875,071			Ps.1,983,170,730

XML

Derivative Financial Instruments

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Derivative Financial Instruments

NOTE 16. DERIVATIVE FINANCIAL INSTRUMENTS

PEMEX faces market risk caused by the volatility of hydrocarbon prices, exchange rates and interest rates, credit risk associated with investments and financial derivatives, as well as liquidity risk. In order to monitor and manage these risks, PEMEX has approved general provisions relating to financial risk management, which are comprised of policies and guidelines that promote an integrated framework for risk management, regulate the use of derivative financial instruments (“DFIs”), and guide the development of risk mitigation strategies.

This regulatory framework establishes that DFIs should be used only for the purpose of mitigating financial risk. The use of DFIs for any other purpose must be approved in accordance with PEMEX’s current internal regulation.

Approved DFIs are mainly traded on the OTC (Over the Counter) market. However exchange traded instruments may also be used. In the case of PMI Trading, DFIs are traded on CME-ClearPort.

One of PEMEX’s policies is to contribute minimizing the impact that unfavorable changes in financial risk factors have on its financial results by promoting an adequate balance between expected incoming cash flows from operations and outgoing cash flows related to its liabilities.

As part of the regulatory framework for financial risk management, PEMEX has established in its internal procedures the eligible counterparties to trade DFIs and other financial instruments.

In addition, certain PMI subsidiaries have implemented a regulatory framework for risk management with respect to its activities, which consists of policies, guidelines and procedures to manage the market risk associated with its commodity trading activities in accordance with industry best practices, such as: 1) the use of DFIs for financial risk mitigation purposes; 2) the segregation of duties; 3) valuation and monitoring mechanisms, such as the generation of a daily portfolio risk report, value at risk (VaR) computation; and 4) VaR limits, both at a global and business unit level and the implementation of stop loss mechanisms. In addition, PMI Trading also has its own risk management subcommittee that supervises the trading of DFIs.

Given that PEMEX’s outstanding DFIs have been entered into for risk mitigation purposes, particularly with economic hedging purposes, it is unnecessary to establish and monitor market risk limits.

For those portfolios with an open market risk exposure, PEMEX’s financial risk management regulatory framework establishes the implementation and monitoring of market risk limits such as VaR and capital at risk (an aggregation of fair value or mark-to-market (“MtM”) and profit and loss, or CaR).

PEMEX has also established credit guidelines for DFIs that Pemex Industrial Transformation offers to its domestic customers, which include the use of guarantees and credit lines. For exchange traded DFIs, PEMEX trades under the margin requirements of the corresponding exchange market, and therefore does not have internal policies for these DFIs.

DFIs held with financial counterparties do not include collateral exchange clauses. Notwithstanding, PEMEX’s regulatory framework promotes credit risk mitigation strategies such as collateral exchange

A. Risk Management

I. Market Risk

i. Interest rate risk

PEMEX is exposed to fluctuations in floating interest rate liabilities. PEMEX is exposed to U.S. dollar LIBOR and to Mexican peso TIIE. As of December 31, 2017, approximately 15.6% of PEMEX’s total net debt outstanding consisted of floating rate debt.

Occasionally, for strategic reasons or in order to offset the expected inflows and outflows, PEMEX has entered into interest rate swaps. Under its interest rate swap agreements, PEMEX acquires the obligation to make payments based on a fixed interest rate and is entitled to receive floating interest rate payments based on LIBOR, TIIE or a rate referenced to or calculated from TIIE.

As of December 31, 2017, PEMEX was a party to four interest rate swap agreements denominated in U.S. dollars for an aggregate notional amount of U.S. $1,623,750 at a weighted average fixed interest rate of 2.35% and a weighted average term of 7.3 years.

Similarly, in order to eliminate the volatility associated with variable interest rates of long-term financing operations, PMI NASA has executed interest rate swap agreements denominated in U.S. dollars for an aggregate notional amount of U.S. $71,936, at a weighted average fixed interest rate of 4.17% and a weighted average term of 4.41 years.

Moreover, PEMEX invests in pesos and U.S. dollars in compliance with applicable internal regulations, through portfolios that have different purposes that seek an adequate return subject to risk parameters that reduce the probability of capital losses. The objective of the investments made through these portfolios is to meet PEMEX’s obligations payable in pesos and U.S. dollars.

The investments made through PEMEX’s portfolios are exposed to domestic and international interest rate risk and credit spread risk derived from government and corporate securities, and inflation risk arising from the relationship between UDIs and pesos. However, these risks are mitigated by established limits on exposure to market risk.

ii. Exchange rate risk

Most of PEMEX’s revenues are denominated in U.S. dollars, a significant amount of which is derived from exports of crude oil and petroleum products, which are priced and payable in U.S. dollars. Additionally, PEMEX’s revenues from domestic sales of gasoline and diesel net of IEPS Tax, tax duties, incentives, and other related taxes, as well as domestic sales of natural gas and its byproducts, LPG and petrochemicals, are referenced to international U.S. dollar-denominated prices.

PEMEX’s expenses related to hydrocarbon duties are calculated based on international U.S. dollar-denominated prices and the cost of hydrocarbon imports that PEMEX acquires for resale in Mexico or use in its facilities are indexed to international U.S. dollar-denominated prices. By contrast, PEMEX’s capital expenditure and operating expenses are established in pesos.

As a result of this cash flow structure, the depreciation of the peso against the U.S. dollar increases PEMEX’s financial balance. The appreciation of the peso relative to the U.S. dollar has the opposite effect. PEMEX manages this risk without the need for hedging instruments, because the impact on PEMEX’s revenues of fluctuations in the exchange rate between the U.S. dollar and the peso is offset in whole or in part by its impact on its obligations.

Therefore, PEMEX prioritizes debt issuances denominated in U.S. dollars; nonetheless, this is not always achievable, hence non-U.S. dollar debt issued in international currencies are hedged through DFIs to mitigate their exchange rate exposure, either by swapping them into U.S. dollars or through other derivative structures. The rest of the debt is denominated in pesos or in UDIs, for which most of the debt denominated in UDIs has been converted into pesos through DFIs in order to eliminate the inflationary risk exposure.

As a consequence of the above, PEMEX’s debt issued in international currencies other than U.S. dollars has exchange rate risk mitigation strategies. PEMEX has selected strategies that further seek to reduce its cost of funding by leaving, in some cases, part of this exchange rate exposure unhedged when assessed appropriate.

The underlying currencies of PEMEX’s DFIs are the euro, Swiss franc, Japanese yen, Pound sterling and Australian dollar versus the U.S. dollar and UDIs versus the peso.

In 2017, PEMEX entered into various cross-currency swaps to hedge inflation risk arising from debt denominated in UDIs, for an aggregate notional amount of Ps. 6,291,969. During 2016, PEMEX entered into the same kind of instruments to hedge currency risk arising from debt obligations denominated in euros and Swiss francs for an aggregate notional amount of U.S. $3,459,236 and the inflation risk arising from debt denominated in UDIs, for an aggregate notional amount of Ps. 1,077,101.

Most of PEMEX’s cross-currency swaps are plain vanilla except for one swap entered into in 2004 to hedge its exposure to the euro, which expired in 2016. This swap was referred to as an “extinguishing swap” and was obtained in order to hedge long-term obligations. The main characteristic of extinguishing swaps was that these DFIs terminate upon the occurrence of any of the credit default events specified in the DFI contract confirmation, without any payment obligation for either party. This swap had a notional amount of U.S. $1,146,410.

In 2016, PEMEX entered into, without cost, an options structure called “Seagull Option” in order to cover the notional risk of a debt issue in Japanese yen for ¥80,000,000, keeping the coupons in the original currency (0.5% annual coupon rate). This structure protects the short exposure in Japanese yen against an appreciation of the Japanese yen versus the U.S. dollar from JPY 83.70 and up to JPY 75.00 and recognizes a benefit if the Japanese yen depreciates to an average of 117.39 JPY/USD.

Moreover, in 2017 PEMEX entered into, without cost, three more Seagull Options to hedge the notional risk of three debt issues in euros for an aggregate notional amount of € 4,250,000. These structures protect the short exposure in euros against an appreciation of the euro versus the U.S. dollar in a specific range, and PEMEX recognizes a benefit if the euro depreciates up to a certain exchange rate, for each debt issue. Whereas, in order to mitigate the exchange rate risk caused by the coupons of these issues PEMEX entered into coupon-only swaps.

Additionally, PEMEX entered into, without cost, a structure which is composed of a cross-currency swap and the sale of a call option, in order to hedge the notional risk of a debt issue in Pound sterling for £450,000, guaranteeing complete protection up to a certain exchange rate and partial protection above that level.

PEMEX recorded a total net foreign exchange gain (loss) of Ps. 23,184,122, Ps. (254,012,743) and Ps. (154,765,574), for the years ended December 31, 2017, 2016 and 2015, respectively; these amounts include the unrealized foreign exchange gain (loss) associated with debt of Ps. 16,685,439, Ps. (243,182,764) and Ps. (152,554,454) for the years ended December 31, 2017, 2016 and 2015, respectively. The appreciation of the peso caused a total net foreign exchange gain because a significant part of PEMEX’s debt, 89.4% (principal only), as of December 31, 2017 is denominated in foreign currency. Unrealized foreign exchange gains and losses do not impact PEMEX’s cash flows. Due to the cash flow structure described above, the depreciation of the peso relative to the U.S. dollar does not affect PEMEX’s ability to meet U.S. dollar-denominated financial obligations and improves PEMEX’s ability to meet peso-denominated financial obligations. On the other hand, the appreciation of the peso relative to the U.S. dollar may increase PEMEX’s peso debt service costs on a U.S. dollar basis. PEMEX’s foreign exchange gain in 2017 was due to the appreciation of the peso, from Ps. 20.6640 = U.S. $1.00 on December 31, 2016 to Ps. 19.7867 = U.S. $1.00 on December 31, 2017. PEMEX’s foreign exchange loss in 2016 was due to the depreciation of the peso, from Ps. 17.2065 = U.S. $1.00 on December 31, 2015 to Ps. 20.6640 = U.S. $1.00 on December 31, 2016. PEMEX’s foreign exchange loss in 2015 was due to the depreciation of the peso, from Ps. 14.7180 = U.S. $1.00 on December 31, 2014 to Ps.17.2065 = U.S. $1.00 on December 31, 2015.

Certain of the PMI subsidiaries face market risks generated by fluctuations in foreign exchange rates. In order to mitigate these risks, the boards of directors of several of these companies have authorized a policy which stipulates that no more than 5% of a company’s total financial assets may be denominated in a currency other than its functional currency, unless the company owes a duty or expected payment in a currency other than its functional one. Accordingly, certain PMI subsidiaries will, from time to time, enter into DFIs in order to mitigate the risk associated with financing operations denominated in currencies other than their respective functional currency.

Finally, a significant amount of PMI Trading’s income and expenses, including the cost of sales and related sales costs, is derived from the trade of refined products, petrochemicals and gas liquids to PEMEX subsidiaries and third parties, whose prices are determined and are payable in U.S. dollars. PMI Trading’s exposure to foreign currency risk results primarily from the need to fund tax payments denominated in domestic currency, as well as certain related sales costs denominated in domestic currency.

PMI Trading believes it can adequately manage the risk created by the payment of taxes in domestic currency without the need to enter into hedging instruments because the exposure to this risk is marginal relative to the total flows of U.S. dollar. In addition, in the event that a potential foreign exchange risk arises in connection with a commercial transaction, PMI Trading may implement risk mitigation measures by entering into DFIs.

iii. Hydrocarbon Price Risk

PEMEX periodically assesses its revenues and expenditures structure in order to identify the main market risk factors that PEMEX’s cash flows are exposed to in connection with international hydrocarbon prices. Based on this assessment, PEMEX monitors its exposure to the most significant risk factors and quantifies their impact on PEMEX’s financial balance.

PEMEX’s exports and domestic sales are directly or indirectly related to international hydrocarbon prices. Therefore, PEMEX is exposed to fluctuations in these prices. In terms of crude oil and natural gas, part of this risk is transferred to the Mexican Government under PEMEX’s current fiscal regime.

PEMEX continuously evaluates the implementation of risk mitigation strategies, including those involving the use of DFIs, while taking into account operational and economic constraints.

PEMEX’s exposure to hydrocarbon prices is partly mitigated by natural hedges between its inflows and outflows.

Since 2016, as a result of the changes in the PEMEX’s fiscal regime, its sensitivity to crude oil prices decreased. Nonetheless, PEMEX worked on a hedging strategy for the following years in order to reduce its exposure to drops in crude oil price.

In April 2017, PEMEX entered into a crude oil hedge to partially protect its cash flows from decreases in the Mexican crude oil basket price below that established in the Ley de Ingresos de la Federación (“Federal Revenue Law”). PEMEX hedged 409 thousand barrels per day from May to December 2017 for U.S. $133,503. As a result of this strategy PEMEX had an income of U.S. $205,705.

During the fourth quarter of 2017, PEMEX entered into a crude oil hedge to partially protect cash flows for the fiscal year 2018 from decreases in the Mexican crude oil basket price below the one established in the 2018 Federal Revenue Law. PEMEX hedged 440 thousand barrels per day from January to December 2018 for U.S. $449,898.

In 2015, PEMEX entered into various swaps in order to hedge the risk arising from the variations of the propane price of its imports. These DFIs were held over a percentage of the total imports volume with maturity dates in 2015. During 2017 and 2016, PEMEX did not enter into any propane import price swaps.

In addition to supplying natural gas, Pemex Industrial Transformation offers DFIs to its domestic customers in order to provide them with support to mitigate the risk associated with the volatility of natural gas prices. Until 2016, Pemex Industrial Transformation entered into DFIs with Mex Gas Supply, S.L. under the opposite position to those DFIs offered to its customers in order to mitigate the market risk it bears under such offered DFIs. Mex Gas Supply, S.L. then transferred the related price risk derived from the DFI position held with Pemex Industrial Transformation to international financial counterparties by entering into these opposite position DFIs with such parties. As of 2017, Pemex Industrial Transformation must enter into DFIs with Petróleos Mexicanos under the opposite position to those DFIs offered to its customers, thereby replacing Mex Gas Supply, S.L. However, as of December 31, 2017, no DFIs have been entered into under this mechanism. Due to the above, Pemex Industrial Transformation maintains a negligible or even null exposure to market risk. These portfolios have VaR and Capital at Risk limits in order to limit market risk exposure.

PMI Trading faces market risk generated by the terms of the purchase and sale of refined products and natural gas liquids, as well as the volatility of oil prices. Accordingly, it frequently enters into DFIs in order to mitigate this risk, thereby reducing the volatility of its financial results.

iv. Risks relating to the portfolio of third-party shares

As of December 31, 2017, Petróleos Mexicanos does not hold any third-party shares of companies that do not participate in financial markets and, therefore, does not hold any related DFIs.

During 2017, PMI HBV liquidated the total shareholding in Repsol, S.A. (Repsol), which was 23,416,219 shares. Therefore, as of December 31, 2017, PEMEX does not hold any third-party shares and does not hold any related DFIs.

v. Market risk quantification

The quantification of market risk exposure in PEMEX’s financial instruments is presented below, in accordance with the applicable international risk management practices.

Interest rate risk quantification

The quantification of interest rate risk of investment portfolios is carried out by using the one-day horizon historical VaR, with a confidence level of 95%, over a period of one year. The VaR incorporates interest rate and spread risks. In addition, for portfolios in domestic currency, the VaR includes the inflation risk embedded in securities denominated in UDI. For portfolio management purposes, interest rate risk is mitigated by VaR limits.

As of December 31, 2017, the VaR of PEMEX’s investment portfolios was Ps. (10.82) for the Peso Treasury Portfolio, Ps. (44.95) for the Fondo Laboral Pemex Portfolio (“FOLAPE”), Ps. (7.17) for the Fideicomiso de Cobertura Laboral y de Vivienda Portfolio (“FICOLAVI”), Ps. (544.32) for the Mexican Peso Treasury Portfolio managed by Operadora de Fondos Nafinsa, S.A. de C.V. (“OFINSA”), and U.S. $0 for the U.S. Dollar Treasury Portfolio.

In addition to the exposure to interest rate fluctuations of the DFIs in which PEMEX is obligated to pay floating rates, PEMEX’s DFIs are exposed to MtM volatility as a result of changes in the interest rate curves used in their valuation.

Interest rate risk quantification was calculated for DFIs in conjunction with the interest rate risk quantification for the debt portfolio. The following table shows the sensitivity of PEMEX’s DFIs and debt portfolio to a parallel shift of 10 basis points (bp) over the zero coupon rate curves. The 10bp parallel shift may be used to estimate in a simple manner the impact for proportional values to this shift and was selected in accordance with market practices for financial risk management.

For the debt portfolio, interest rate risk sensitivity was calculated taking into account both the DFI interbank market yield curves and the PEMEX curves (which were also used to estimate the debt portfolios’ fair value). These metrics were calculated solely for informational purposes and are not used for portfolio management purposes because PEMEX does not intend to prepay its debt or terminate its DFIs early. Therefore, there is no interest rate risk arising from fixed rate obligations.

INTEREST RATE and CURRENCY DFIs

Interest rate sensitivity to + 10 bp
	Interbank Yield Curves							PEMEX Curves Sensitivity debt
Currency	Sensitivity debt		Sensitivity DFIs			Sensitivity net
in thousands U.S. dollars
CHF		3,144		(3,144	)		—		3,030
Euro		100,081		(84,962	)		15,119		82,839
Pound Sterling		7,691		(7,073	)		618		6,587
Yen		8,542		(3,972	)		4,570		6,877
Peso		43,774		2,039			45,813		42,012
UDI		16,496		(11,586	)		4,910		15,453
U.S. dollar		785,508		89,880			875,388		416,052

FX swaps were included in the calculation of the figures in the previous table, which were not traded as debt hedging.

In addition, PEMEX performed a retrospective sensitivity analysis of the impact on its financial statements for the years ended December 31, 2017, 2016 and 2015, in which PEMEX assumed either an increase or decrease of 25 basis points in the floating interest rates of its debt and corresponding hedges.

At December 31, 2017, 2016 and 2015, had market interest rates been 25 basis points higher, with all other variables remaining constant, net income for the year would have been Ps. 704,011, Ps. 841,024 and Ps. 922,268 lower for December 31, 2017, 2016 and 2015, respectively, primarily as a result of an increase in interest expense. Conversely, had market interest rates been 25 basis points lower, net income for the year would have been Ps. 704,011, Ps. 841,024 and Ps. 922,268 greater at December 31, 2017, 2016 and 2015, respectively, primarily as a result of a decrease in interest expense.

Exchange rate risk quantification

The investments of PEMEX’s portfolios do not face foreign exchange rate risk because the funds of such portfolios are used to meet obligations in pesos and U.S. dollars.

Currency DFIs are entered into in order to hedge exchange rate risk arising from debt flows in currencies other than pesos and U.S. dollars or inflation risk arising from debt flows in UDIs. However, due to the accounting treatment, net income is exposed to mark-to-market volatility as a result of changes in the exchange rates used in their valuation.

Exchange rate risk quantification was calculated for DFIs in conjunction with the exchange rate risk quantification for the debt portfolio. The following table shows the sensitivity of PEMEX’s DFIs and debt portfolio to an increase of 1% to the exchange rates of currencies against the U.S. dollar. The 1% may be used to estimate in a simple manner the impact for proportional values to this increase and was selected in accordance with market practices for financial risk management.

For the debt portfolio, exchange rate risk sensitivity was calculated taking into account both, interbank market yield curves and the PEMEX curves. In addition, the table shows the one-day horizon historical VaR of the remaining open position, with a confidence level of 95%, over a period of one year. These metrics were calculated solely for informational purposes. Nevertheless, in order to carry out management activities related to its debt portfolio, PEMEX periodically conducts quantitative analyses in order to estimate the exchange rate risk exposure generated by its debt issuances. Based on these analyses, PEMEX has elected to enter into DFIs as an exchange rate risk mitigation strategy.

INTEREST RATE and CURRENCY DFIs

	Interbank Yield Curves											PEMEX Curves 1% Debt
Currency	1% Debt			1% DFIs		1% Net			VaR 95% Net
in thousands U.S. dollars
CHF		(13,943	)		13,943		—			—			(13,624	)
Euro		(187,988	)		165,894		(22,094	)		(19,744	)		(167,068	)
Pound Sterling		(13,822	)		13,042		(780	)		(666	)		(12,322	)
Yen		(16,914	)		11,470		(5,444	)		(4,398	)		(14,859	)
Peso		(135,974	)		1,409		(134,565	)		(162,336	)		(133,525	)
UDI		(29,485	)		25,358		(4,127	)		(5,038	)		(28,573	)

As shown in the table above, exchange rate risk derived from debt denominated in currencies other than pesos and U.S. dollars is almost fully hedged by DFIs.

The exchange rate risk exposure to the euro, Pound sterling and Japanese yen is result of the delta of the structures described above (Seagull Options and Calls).

FX swaps which were not traded as part of debt hedging were included in the calculation of the figures in the table above.

In addition, PEMEX performed a retrospective sensitivity analysis of the impact on its financial statements of the years ended December 31, 2017, 2016 and 2015, in which PEMEX assumed either an increase or decrease of 10% in the exchange rate between the U.S. dollar and peso in order to determine the impact on net income and equity as a result of applying these new rates to the monthly balances of assets and liabilities denominated in U.S. dollars.

At December 31, 2017, 2016 and 2015, had the peso depreciated against the U.S. dollar by 10% with other variables remaining constant, net income would have been Ps.149,669, Ps.124,512 and Ps.105,915 lower, respectively, primarily as a result of an increase in the exchange rate losses. However, had the peso appreciated against the U.S. dollar by 10%, net income for the period would have increased by Ps.149,669, Ps.124,512 and Ps.105,915, respectively, primarily as a result of the decrease in exchange rate losses.

Hydrocarbon price risk quantification

Pemex Industrial Transformation occasionally faces market risk due to open positions arising from the mismatch between the DFI portfolio offered to domestic customers and hedges with international counterparties. As of December 31, 2017, Pemex Industrial Transformation’s natural gas DFI portfolio had no market risk exposure.

Market risk exposure is measured using the 20-day Delta-Gamma VaR methodology, with a confidence level of 95%, based on 500 daily observations; VaR and CaR are monitored and mitigated by pre-established limits.

It should be noted that sensitivity analyses were not carried out for other financial instruments, such as accounts receivable and payable (as defined in the financial reporting standards). Such accounts are cleared in short-term, and therefore market risk is considered to be nonexistent. Most of these accounts are related to hydrocarbon prices.

In accordance with the risk management regulatory framework that PMI Trading has implemented, VaR and the change in profit and loss by portfolio are calculated daily and compared to the maximum applicable limits in order to implement risk mitigation mechanisms as necessary.

PMI Trading’s global VaR associated with commodities market risk was U.S. $(8,789) as of December 31, 2017. This VaR was calculated using the historical method with a 99% confidence level, two-year history and a one-day horizon. The minimum VaR recorded on the year was U.S. $(4,720) (registered on October 17, 2017) and the maximum VaR recorded on the year was U.S. $(19,695) (registered on January 4, 2017). As of December 31, 2016, the global VaR was U.S. $(23,198).

The quantification of crude oil price risk is carried out by using the one-day horizon historical VaR, with a confidence level of 95%, over a period of one year. As of December 31, 2017, this was U.S. $0 as a result of the rise in the price of crude oil.

II. Credit Risk

When the fair value of a DFI is favorable to PEMEX, PEMEX faces the risk that the counterparty will not be able to meet its obligations. PEMEX monitors its counterparties’ creditworthiness and calculates the credit risk exposure for its DFIs. As a risk mitigation strategy, PEMEX only enters into DFIs with major financial institutions with a minimum credit rating of BBB-. These ratings are issued and revised periodically by risk rating agencies. Furthermore, PEMEX seeks to maintain a diversified portfolio of counterparties.

In order to estimate PEMEX’s credit risk exposure to each financial counterparty, the potential future exposure is calculated by projecting the risk factors used in the valuation of each DFI in order to estimate the MtM value for different periods, taking into account any credit risk mitigation provisions.

Moreover, PEMEX has entered into various long-term cross-currency swaps agreements with “recouponing” provisions (pursuant to which the payments on the swaps are adjusted when the MtM exceeds the relevant threshold specified in the swap), thereby limiting the exposure with its counterparties to a specific threshold amount. The specified thresholds were reached in three cross-currency swaps from the first to the fourth quarter of 2017, which were used to hedge the exchange rate exposure to the euro and in five cross-currency swaps during 2016, which were used to hedge the exchange rate exposure to the Pound sterling. This resulted in the cash settlement of such swaps and the resetting of swap terms to return their mark-to-market value to zero. During 2017, PEMEX did not enter into any cross-currency swap with these characteristics.

In addition, during 2016 PEMEX entered into long-term DFIs with mandatory early termination clauses (pursuant to which, at a given date and irrespective of the current MtM, the DFI will terminate and settle at the corresponding MtM, and PEMEX can either enter into a new DFI with the same counterparty or a new counterparty), which reduces the credit risk generated by the term of the DFI by bounding it to a specific date. As of December 31, 2017, PEMEX has entered into three euro swaps and two Japanese yen Seagull Option structures, with termination clauses in 2018 and 2021, respectively.

According to IFRS 13 “Fair Value Measurement,” the fair value or MtM value of DFIs must reflect the creditworthiness of the parties. Consequently, the fair value of a DFI takes into account the risk that either party may default on its obligation. In accordance with market best practices, PEMEX applies the credit value adjustment (“CVA”) method to calculate the fair value of its DFIs.

For each DFI, the CVA is calculated by determining the difference between the MtM and the estimated MtM adjusted for credit risk. In determining the credit risk, the CVA method takes into account the current market perception about the credit risk of both counterparties, using the following inputs: a) the MtM projection for each payment date based on forward yield curves; b) the implied default probability obtained from both, PEMEX and the counterparty credit default swaps’, at each payment date; and c) the default recovery rates of each counterparty.

The current and potential exposures, aggregated by credit rating, are as follows:

Maximum Credit Exposure by term in Petróleos Mexicanos
Rating	Current		Less than 1 year		1-3 years		3-5 years		5-7 years		7-10 years		More than 10 years
in thousands U.S. dollars
A		257,424		976,230		1,298,110		1,314,296		578,548		482,959		—
A-		138,850		235,594		191,681		228,801		223,751		257,465		—
BBB+		310,705		1,010,356		1,540,015		1,349,311		1,243,898		1,115,559		78,831
BBB		2,183		18,626		20,064		18,092		—		—		—

PEMEX also faces credit risk derived from its investments. As of December 31, 2017, the notional amounts of investments in domestic currency, organized by the credit ratings of the issuances, were as follows:

Credit rating of issuances*	Notional amount
mxAAA		Ps.        811,548
mxAA		200,876
mxA		271,275
* Minimum S&P, Moody’s and Fitch credit rating.
National Credit Rating Scale.
Does not include investments in Mexican Government bonds.

The table above does not include domestic currency Mexican Government bonds because these issuances are considered not to carry default risk in this currency.

PEMEX held an investment in a note linked to United Mexican States’ credit risk that was issued by a U.S. financial institution with a BBB+ credit rating. This note matured in June 2016 and had a face value of U.S. $108,000. As of December 31, 2017, PEMEX does not hold an investment in structured notes.

Furthermore, by means of its credit guidelines for DFI operations, Pemex Industrial Transformation has significantly reduced its credit risk exposure related to the DFIs offered to its customers to assist them in mitigating the risk associated with the volatility of natural gas.

In order to qualify for these DFIs, Pemex Industrial Transformation’s customers must be party to a current natural gas supply contract and sign a domestic master derivative agreement.

Additionally, beginning on October 2, 2009, DFIs with these customers must be initially secured by cash deposits, letters of credit or other collateral provisions, as required. In accordance with these guidelines, in the event that a client does not meet its payment obligations, DFIs related to this client are terminated, rights to collateral are exercised and, if the collateral is insufficient to cover the fair value, natural gas supply is suspended until the payment is made.

On August 20, 2014, certain amendments to the credit guidelines were enacted, which allowed Pemex-Gas and Petrochemicals, and now Pemex Industrial Transformation, to offer to its clients with an adequate credit rating, based on an internal financial and credit assessment, DFIs with an exemption from collateral requirements up to certain amount through a credit line approved by the credit committee. Moreover, if the credit line is insufficient to cover each client’s exposure, the client is obligated to deposit collateral. If a client suffers an event of default, DFIs related to this client are terminated early and natural gas supply is suspended until the payment is made.

As of December 31, 2017, Pemex Industrial Transformation’s DFIs had a fair value of U.S. $1,464 (deferred premiums included) for clients with exempted credit lines and U.S. $8,183 for clients with guaranteed credit lines. The total amount of exempt credit lines rose to U.S. $117,956, representing 1% usage of available exempt credit lines, while the total amount of guaranteed credit lines rose to U.S. $930,199, representing a 1% usage of available guaranteed credit lines.

As of December 31, 2017, the overdue accounts of natural gas customers in the industrial and distribution sectors accounted for less than 1.00% of the total sales of Pemex Industrial Transformation.

As of December 31, 2017, Pemex Industrial Transformation had open DFIs with 8 customers. Of the total volume (in millions of British thermal units or MMBtu) of DFIs, industrial customers represented 100%.

As of December 31, 2017 and 2016, Pemex Industrial Transformation had not provided any collateral for DFIs entered into to hedge its DFIs with customers. This was due to the following: (i) natural gas prices maintained levels below the strike price, which has kept the credit limits within the set limits; and (ii) when certain DFIs matured, Pemex-Gas and Basic Petrochemicals, and now Pemex Industrial Transformation, had used domestic customers’ payments to meet its international obligations.

The potential future exposure of Mex Gas Supply, S.L.’s DFI portfolio was calculated in an analogous manner to the analysis of Petróleos Mexicanos’ DFI positions. The current and potential exposure, aggregated by credit rating, is as follows:

Maximum Credit Exposure by term in Pemex Industrial Transformation
Rating	Current		Less than 1 year		1-3 years		3-5 years		5-7 years		7-10 years		More than 10 years
in thousands U.S. dollars
A		27		27		—		—		—		—		—
A-		541		541		306		—		—		—		—
BBB+		25		25		1		—		—		—		—

PMI Trading’s credit risk associated with DFI transactions is mitigated through the use of futures and standardized instruments that are cleared through CME-ClearPort.

III. Liquidity Risk

Through its debt planning and the purchase and sale of U.S. dollars, PEMEX currently preserves a cash balance at a level of liquidity in domestic currency and U.S. dollars that is considered adequate to cover its investment and operating expenses, as well as other payment obligations. In order to preserve a cash balance at a suitable level, in December of 2017, PEMEX entered into ten FX swaps of the peso against U.S. dollar for an aggregate amount of U.S. $3,000,000.

In addition, PEMEX has acquired committed revolving credit lines in order to mitigate liquidity risk, two of which provide access to Ps. 3,500,000 and Ps. 20,000,000 with expiration dates in June and November 2019, respectively; and three others that each provide access to U.S. $1,500,000, U.S. $3,250,000 and U.S. $1,950,000 with expiration dates in December 2019, February 2020 and January 2021, respectively.

Finally, the investment strategies of PEMEX’s portfolios are structured by selecting time horizons that consider each currency’s cash flow requirements in order to preserve liquidity.

Certain PMI subsidiaries mitigate their liquidity risk through several mechanisms, the most important of which is the centralized treasury or “in-house bank,” which provides access to a syndicated credit line for up to U.S. $700,000 and cash surplus capacity in the custody of the centralized structure. In addition, certain PMI subsidiaries have access to bilateral credit lines from financial institutions for up to U.S. $650,000.

These companies monitor their cash flow on a daily basis and protect their creditworthiness in the financial markets. Liquidity risk is mitigated by monitoring the maximum/minimum permissible financial ratios as set forth in the policies approved by each company’s board of directors.

The following tables show the cash flow maturities as well as the fair value of PEMEX’s debt and DFI portfolios as of December 31, 2017 and 2016. It should be noted that:

• For debt obligations, these tables present principal cash flow and the weighted average interest rates for fixed rate debt.

• For interest rate swaps, cross currency swaps, currency options and currency forwards, these tables present notional amounts and weighted average interest rates by expected (contractual) maturity dates.

• Weighted average variable rates are based on implied forward rates obtained from the interbank market yield curve at the reporting date.

• For natural gas DFIs, volumes are presented in millions of British thermal unit (MMBtu), and fixed average and strike prices are presented in U.S. dollars per MMBtu.

• For crude oil, volumes are presented in millions of barrels, and fixed average and strike prices are presented in U.S. dollars per barrel.

• A DFI’s fair value includes CVA and is calculated based on market quotes obtained from market sources such as Bloomberg. Forward curves and implied volatilities for natural gas and crude oil are supplied by the Kiodex Risk Workbench platform.

• For PMI Trading, the prices used in commercial transactions and DFIs are published by reputable sources that are widely used in international markets, such as CME-NYMEX, Platts and Argus, among others.

• Fair value is calculated internally, either by discounting cash flows with the corresponding zero-coupon yield curve in the original currency, or through other standard methodologies commonly applied in financial markets for specific instruments.

• For all instruments, tables are based on the contract terms in order to determine the future cash flows that are categorized by expected maturity dates.

This information is presented in thousands of pesos, except as noted.

Quantitative Disclosure of Debt Cash Flow’s Maturities as of December 31, 2017⁽¹⁾

	Year of expected maturity date
	2018		2019		2020		2021		2022		2023 thereafter		Total carrying value			Fair value
Liabilities
Outstanding debt
Fixed rate (U.S. dollars)	Ps	53,465,817	Ps	59,498,256	Ps	60,290,621	Ps	95,232,448	Ps	84,076,050	Ps	808,836,547	Ps	1,161,399,739		Ps	. 1,213,404,769
Average interest rate (%)														5.7747	%
Fixed rate (Japanese yen)		—		—		—		—		—		19,296,607		19,296,607			18,040,398
Average interest rate (%)														1.3485	%
Fixed rate (Pounds)		—		—		—		—		9,345,839		11,952,816		21,298,655			24,381,394
Average interest rate (%)														5.7246	%
Fixed rate (pesos)		—		—		10,033,017		20,376,655		1,999,098		88,349,072		120,757,842			171,683,692
Average interest rate (%)														7.4876	%
Fixed rate (UDIs)		—		18,477,076		4,764,175		3,874,313		—		30,081,647		57,197,211			56,536,905
Average interest rate (%)														2.7458	%
Fixed rate (euros)		1,043		32,042,196		30,801,894		41,508,857		23,655,950		171,255,634		299,265,574			330,573,998
Average interest rate (%)														3.6736	%
Fixed rate (Swiss Francs)		4,565,075		6,088,686		12,149,953		3,046,567		—		—		25,850,281			26,957,785
Average interest rate (%)														1.8387	%
Fixed rate (Australian dollars)		—		—		—		—		—		—		—			—
Average interest rate (%)		—		—		—		—		—		—		—			—
Total fixed rate debt		58,031,935		116,106,214		118,039,660		164,038,840		119,076,937		1,129,772,323		1,705,065,909			1,841,578,940
Variable rate (U.S. dollars)		58,364,536		15,302,101		62,289,546		12,809,666		31,289,725		18,379,557		198,435,131			206,254,219
Variable rate (Japanese yen)		—		—		11,244,800		—		—		—		11,244,800			11,361,079
Variable rate (pesos)		8,734,371		27,995,083		18,341,742		8,459,163		8,394,483		19,125,764		91,050,606			94,188,981
Total variable rate debt		67,098,907		43,297,184		91,876,088		21,268,829		39,684,208		37,505,321		300,730,537			311,804,280
Total debt	Ps	. 125,130,842	Ps	. 159,403,398	Ps	. 209,915,748	Ps	. 185,307,669	Ps	. 158,761,145	Ps	.1,167,277,644	Ps	. 2,005,796,446		Ps	.2,153,383,220

Note: Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2017 of: Ps. 19.7867 = U.S. $1.00; Ps. 0.1757 = 1.00 Japanese yen; Ps. 26.7724 = 1.00 Pound sterling; Ps. $ 5.934551 = 1.00 UDI; Ps. 23.7549 = 1.00 euro; Ps. 20.2992 = 1.00 Swiss Franc; and Ps. 15.4752 = 1.00 Australian dollar.

Source: PEMEX

Quantitative Disclosure of Debt Cash Flow’s Maturities as of December 31, 2016⁽¹⁾

	Year of expected maturity date
	2017		2018		2019		2020		2021		2022 thereafter		Total carrying value			Fair value
Liabilities
Outstanding debt
Fixed rate (U.S. dollars)		Ps 15,759,027	Ps	86,161,096	Ps	65,642,616	Ps	62,440,943	Ps	98,858,992	Ps	826,093,574	Ps	1,154,956,248		Ps	1,137,936,275
Average interest rate (%)														5.6541	%
Fixed rate (Japanese yen)		517,286		—		—		—		—		19,459,306		19,976,592			17,336,203
Average interest rate (%)														1.3665	%
Fixed rate (Pounds)		—		—		—		—		—		8,825,434		8,825,434			11,373,345
Average interest rate (%)														8.2500	%
Fixed rate (pesos)		—		—		—		10,048,950		20,457,671		90,393,507		120,900,128			160,930,040
Average interest rate (%)														7.4878	%
Fixed rate (UDIs)		—		—		17,319,897		4,464,787		3,630,557		28,288,180		53,703,421			50,809,979
Average interest rate (%)														4.0559	%
Fixed rate (euros)		26,006,880		—		29,198,138		28,061,554		—		123,886,644		207,153,216			216,100,006
Average interest rate (%)														3.9581	%
Fixed rate (Swiss Francs)		—		4,539,022		6,056,338		12,102,748		3,031,480		—		25,729,588			26,469,543
Average interest rate (%)														1.8385	%
Fixed rate (Australian dollars)		2,232,195		—		—		—		—		—		2,232,195			2,346,390
Average interest rate (%)		—		—		—		—		—		—		6.1250	%		—
Total fixed rate debt		44,515,388		90,700,118		118,216,989		117,118,982		125,978,700		1,096,946,645		1,593,476,822			1,623,301,781
Variable rate (U.S. dollars)		38,811,320		27,907,661		15,984,547		52,726,647		13,366,336		45,385,885		194,182,396			195,838,382
Variable rate (Japanese yen)		—		—		—		11,341,440		—		—		11,341,440			11,025,531
Variable rate (euros)		—		—		—		—		—		—		—			—
Variable rate (pesos)		65,024,075		8,742,191		28,007,709		18,347,822		8,468,176		27,764,693		156,354,666			158,109,920
Total variable rate debt		103,835,395		36,649,852		43,992,256		82,415,909		21,834,512		73,150,578		361,878,502			364,973,833
Total debt	Ps.	148,350,783	Ps.	127,349,970	Ps.	162,209,245	Ps.	199,534,891	Ps.	147,813,212	Ps.	1,170,097,223	Ps.	1,955,355,324		Ps.	1,988,275,614

Note: Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2016 of: Ps. 20.664 = U.S. $1.00; Ps. 0.17721 = 1.00 Japanese yen; Ps. 25.30513 = 1.00 Pound sterling; Ps. $ 5.562883 = 1.00 UDI; Ps. 21.6724 = 1.00 euro; Ps. 20.19744= 1.00 Swiss Franc; and Ps. 14.88428 = 1.00 Australian dollar.

Source: PEMEX

Quantitative Disclosure of Cash Flow’s Maturities from Derivative Financial Instruments Held or Issued for Purposes Other than Trading as of December 31, 2017⁽¹⁾⁽²⁾

	Year of expected maturity date																		Total Notional Amount		Fair Value(3)
	2018			2019			2020			2021			2022			2023 Thereafter
Hedging instruments(2)(4)
Interest rate DFIs
Interest rate swaps (U.S. dollars)
Variable to fixed		Ps. 4,704,170			Ps. 4,717,321			Ps. 4,730,857			Ps. 4,686,396			Ps 4,570,070			Ps 10,143,209			Ps. 33,552,022		Ps. 388,851
Average pay rate		3.16	%		3.18	%		3.20	%		3.22	%		3.26	%		3.48	%		N.A.		N.A.
Average receive rate		3.19	%		3.44	%		3.69	%		3.81	%		3.95	%		4.48	%		N.A.		N.A.
Interest rate swaps (pesos)
Variable to fixed		—			—			—			—			—			—			—		—
Average pay rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Average receive rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Currency DFIs
Cross-currency swaps
Receive euros/Pay U.S. dollars		—			29,898,198			28,719,208			36,902,690			21,302,856			161,617,172			278,440,124		19,065,727
Receive Japanese yen/ Pay U.S. dollars		—			—			13,039,563			—			—			4,775,551			17,815,114		(1,670,533	)
Receive Pounds sterling/ Pay U.S. dollars		—			—			—			—			10,310,216			11,706,999			22,017,215		1,151,096
Receive UDI/ Pay pesos		—			23,740,341			7,292,520			3,000,000			—			20,605,166			54,638,028		(4,720,592	)
Receive Swiss francs/ Pay U.S. dollars		4,535,474			6,501,082			11,548,658			2,994,374			—			—			25,579,588		400,316
Receive Australian dollars/ Pay U.S. dollars		—			—			—			—			—			—			—		—
Currency Options
Buy Put, Sell Put and Sell Call on Japanese yen		—			—			—			—			—			14,046,320			14,046,320		48,715
Buy call, Sell call and Sell Put on euros		—			—			—			41,567,998			—			59,382,855			100,950,853		4,919,444
Sell Call on Pound sterling		—			—			—			—			—			12,031,728			12,031,728		(239,626	)
Currency Forwards
Receive U.S. dollars / Pay pesos		59,360,100			—			—			—			—			—			59,360,100		(2,006,461	)

N.A. = not applicable.

Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2017 of: Ps. 19.7867 = U.S. $1.00 and Ps. 23.7549 = 1.00 euro.

(2) PEMEX’s management uses these DFIs to hedge market risk; however, these DFIs do not qualify for accounting purposes as hedges and are recorded in the financial statements as entered into for trading purposes.

(3) Positive numbers represent a favorable fair value to PEMEX.

(4) PMI’s risk management policies and procedures establish that DFIs should be used only for hedging purposes; however DFIs are not recorded as hedges for accounting purposes.

Source: PEMEX

Quantitative Disclosure of Cash Flow’s Maturities from Derivative Financial Instruments Held or Issued for Purposes Other than Trading as of December 31, 2016⁽¹⁾⁽²⁾

	Year of expected maturity date																		Total Notional Amount		Fair Value(3)
	2017			2018			2019			2020			2021			2022 Thereafter
Hedging instruments(2)(4)
Interest rate DFIs
Interest rate swaps (U.S. dollars)
Variable to fixed		Ps. 4,899,645			Ps. 4,912,743			Ps. 4,926,477			Ps. 4,940,613			Ps 4,894,180			Ps 15,365,634			Ps. 39,939,292		Ps. 164,716
Average pay rate		2.76	%		2.66	%		3.35	%		3.83	%		4.04	%		4.57	%		N.A.		N.A.
Average receive rate		2.95	%		2.99	%		3.03	%		3.06	%		3.11	%		3.33	%		N.A.		N.A.
Interest rate swaps (pesos)
Variable to fixed		—			—			—			—			—			—			—		—
Average pay rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Average receive rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Currency DFIs
Cross-currency swaps
Receive euros/Pay U.S. dollars		34,775,198			—			31,223,821			29,992,556			—			133,024,913			229,016,488		(16,484,533	)
Receive Japanese yen/ Pay U.S. dollars		532,711			—			—			17,697,534			—			4,987,289			23,217,534		(6,132,633	)
Receive Pounds sterling/ Pay U.S. dollars		—			—			—			—			—			10,767,349			10,767,349		(211,207	)
Receive UDI/ Pay pesos		—			—			23,740,341			3,540,220			3,000,000			14,313,198			44,593,759		(2,132,236	)
Receive Swiss francs/ Pay U.S. dollars		—			4,736,567			6,789,326			12,060,700			3,127,139			—			26,713,732		(789,449	)
Receive Australian dollars/ Pay U.S. dollars		2,459,429			—			—			—			—			—			2,459,429		(126,796	)
Currency Options
Buy Put, Sell Put and sell Call on yen		—			—			—			—			—			14,133,580			14,133,580		(301,131	)

N.A. = not applicable.

Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2016 of: Ps. 20.664 = U.S. $1.00 and Ps. 21.6724 = 1.00 euro.

(2) PEMEX’s management uses these DFIs to hedge market risk; however, these DFIs do not qualify for accounting purposes as hedges and are recorded in the financial statements as entered into for trading purposes.

(3) Positive numbers represent a favorable fair value to PEMEX.

(4) PMI’s risk management policies and procedures establish that DFIs should be used only for hedging purposes; however DFIs are not recorded as hedges for accounting purposes.

Source: PEMEX

B. Fair value of derivative financial instruments

PEMEX periodically evaluates its exposure to international hydrocarbon prices, interest rates and foreign currencies and uses derivative instruments as a mitigation mechanism when potential sources of market risk are identified.

PEMEX monitors the fair value of its DFI portfolio on a periodic basis. The fair value represents the price at which one party would assume the rights and obligations of the other and is calculated for DFIs through models commonly used in the international financial markets, based on inputs obtained from major market information systems and price providers. As a result of this monitoring, PEMEX does not employ an independent third party to perform the valuation.

PEMEX’s DFIs portfolio is composed primarily of swaps, the prices of which are estimated by discounting flows using the appropriate factors and contains no exotic instruments that require numerical approximations for their valuation.

Embedded derivatives

In accordance with established policies, PEMEX has analyzed the different contracts it has entered into and has determined that according to the terms thereof, none meet the criteria necessary to be classified as embedded derivatives. Accordingly, as of December 31, 2017 and 2016, PEMEX did not recognize any embedded derivatives (foreign currency or index).

Accounting treatment

PEMEX enters into derivatives transactions with the sole purpose of hedging financial risks related to its operations, firm commitments, planned transactions and assets and liabilities recorded on its statement of financial position. Nonetheless, some of these transactions do not qualify for hedge accounting treatment because they do not meet the requirements of the accounting standards for designation as hedges. They are therefore recorded in the financial statements as non-hedge instruments or as instruments entered into for trading purposes, despite the fact that their cash flows are offset by the cash flows of the positions (assets or liabilities) to which they relate. As a result, the changes in their fair value are recognized in the “Derivative financial instruments (cost) income, net” line item in the consolidated statement of comprehensive income.

As of December 31, 2017 and 2016, the net fair value of PEMEX’s DFIs (including both DFIs that have not reached maturity and those that have reached maturity but have not been settled), recognized in the consolidated statement of financial position, was Ps. 12,367,475 and Ps. (26,010,486), respectively. As of December 31, 2017 and 2016, PEMEX did not have any DFIs designated as hedges.

The following table shows the fair values and notional amounts of PEMEX’s OTC DFIs that were designated as non-hedges for accounting purposes and entered into for trading purposes as of December 31, 2017 and 2016. It should be noted that:

• A DFI’s fair value includes CVA and is calculated based on market quotes obtained from market sources such as Bloomberg. Forward curves and implied volatilities for natural gas and crude oil are supplied by the Kiodex Risk Workbench platform.

• Fair value is calculated internally, either by discounting cash flows with the corresponding zero-coupon yield curve, in the original currency, or through other standard methodologies commonly applied in the financial markets for certain specific instruments.

• The information is presented in thousands of pesos (except as noted).

		December 31, 2017						December 31, 2016
DFI	POSITION	Notional Amount			Fair Value			Notional Amount			Fair Value
Interest rate swaps	PEMEX pays fixed in U.S. dollar and receives floating in 3-month U.S. dollar LIBOR + spread.		Ps.16,695,028			Ps.   79,448			Ps.20,018,250		Ps.	(90,451	)
Interest rate swaps	PEMEX pays fixed in U.S. dollar and receives floating in 6-month U.S. dollar LIBOR + spread.		15,433,626			332,273			18,132,660			312,210
Cross-currency swaps	PEMEX pays fixed in pesos and receives notional in UDI.		23,740,341			(4,504,151	)		23,740,341			(4,815,373	)
Cross-currency swaps	PEMEX pays the 28-day TIIE + spread in pesos and receives fixed in UDI.		30,897,687			(216,441	)		20,853,418			2,683,138
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in Japanese yen.		4,775,551			134,461			5,520,000			(116,507	)
Cross-currency swaps	PEMEX pays floating in 6-month U.S. dollar LIBOR + spread and receives floating in 6-month yen LIBOR + spread.		13,039,563			(1,804,993	)		17,697,534			(6,016,126	)
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in euro.		278,440,124			19,065,727			229,016,488			(16,484,533	)
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in Pound sterling.		11,706,999			590,113			—			—
Cross-currency swaps	PEMEX pays floating in 6-month U.S. dollar LIBOR + spread and receives fixed in Pound sterling.		10,310,216			560,982			10,767,349			(211,207	)
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in CHF.		25,579,588			400,316			26,713,732			(789,449	)
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in AUD.		—			—			2,459,429			(126,796	)
Currency Options	PEMEX Buy Put, Sell Put and Sell Call on Japanese yen.		14,046,320			48,715			14,133,580			(301,131	)
Currency Options	PEMEX Buy call, Sell call and Sell Put on euros.		100,950,853			4,919,444			—			—
Currency Options	PEMEX Sell Call on Pound sterling		12,031,728			(239,626	)		—			—
Currency Forward	PEMEX pays Pesos and receives U.S. dollar.		59,360,100			(2,006,461	)		—			—
Natural gas swaps	PEMEX receives fixed.		(51,724	)		6,934			(160,214	)		(25,145	)
Natural gas swaps	PEMEX receives floating.		50,846			(6,114	)		157,545			27,869
Natural gas options	PEMEX Long Call.		18,625			398			73,653			11,548
Natural gas options	PEMEX Short Call.		(18,625	)		(397	)		(73,653	)		(11,488	)
Interest rate swaps	PEMEX pays fixed in U.S. dollar and receives floating in U.S. dollar LIBOR 1M.		1,423,368			(22,870	)		1,788,382			(57,043	)
						Ps.17,337,760					Ps.	(26,010,486	)

	December 31, 2017					December 31, 2016
DFI	Volume (MMb)		Fair Value			Volume (MMb)		Fair Value
Crude Oil Options		153.56	Ps.	(5,010,187	)		—		—

			December 31, 2017					December 31, 2016
DFI	Market		Volume (MMb)		Fair value			Volume (MMb)		Fair value
Futures		Exchange traded		2.1	Ps	. (141,693	)		—	Ps.	—
Petroleum Products Swaps		Exchange traded		1.3	Ps	.   (99,680	)		4.1	Ps.	(688,016	)

Notes: Numbers may not total due to rounding.

(1) The fair value of the Futures and the Petroleum Products Swaps, was recognized as “Cash and cash equivalents” in the statement of financial position because PEMEX considered these financial assets to be fully liquid.

The exchange rate for U.S. dollars as of December 31, 2017 and 2016 was Ps. 19.7867 and Ps. 20.6640 per U.S. dollar, respectively. The exchange rate for euros as of December 31, 2017 and 2016 was Ps. 23.7549 and Ps. 21.6724 per euro, respectively.

For the years ended December 31, 2017, 2016 and 2015, PEMEX recognized a net gain (loss) of Ps. 25,338,324, Ps. (14,000,987) and Ps. (21,449,877), respectively, in the “Derivative financial instruments (cost) income, net” line item with respect to DFIs treated as instruments entered into for trading purposes.

The following table presents the fair value of PEMEX’s DFIs that are showed on the consolidated statement of financial position in derivative financial instruments (including both DFIs that have not reached maturity and those that have reached maturity but have not been settled), as of December 31, 2017 and 2016:

	Derivatives assets Fair value
	2017		2016
Derivatives not designated as hedging instruments
Crude oil options	Ps.	397,630	Ps.	—
Currency options		4,968,159		—
Natural gas options		398		11,548
Cross-currency swaps		24,126,452		4,503,550
Natural gas swaps		7,003		30,162
Propane swaps		—		—
Interest rate swaps		411,721		312,210
Others		202,091		—
Total derivatives not designated as hedging instruments		30,113,454		4,857,470
Total assets	Ps.	30,113,454	Ps.	4,857,470

	Derivatives liabilities Fair value
	2017			2016
Derivatives not designated as hedging instruments
Forwards	Ps.	(2,006,461	)	Ps.	—
Futures		—			—
Crude oil options		(5,407,817	)		—
Currency options		—			(301,131	)
Natural gas options		(397	)		(11,488	)
Cross-currency swaps		(10,301,983	)		(30,380,405	)
Natural gas swaps		(6,182	)		(27,438	)
Propane swaps		—			—
Interest rate swaps		(22,870	)		(147,494	)
Others		(269	)		—
Total derivatives not designated as hedging instruments		(17,745,979	)		(30,867,956	)
Total liabilities	Ps.	(17,745,979	)	Ps.	(30,867,956	)
Net total	Ps.	12,367,475		Ps.	(26,010,486	)

The following tables present the net gain (loss) recognized in income on PEMEX’s DFIs for the years ended December 31, 2017, 2016 and 2015, in the consolidated statement of comprehensive income which is presented in the line “Derivative financial instruments (cost) income, net”:

Derivatives not designated as hedging instruments	Amount of gain (loss) recognized in the Statement of comprehensive income
	2017			2016			2015
Forwards	Ps.	(1,976,241	)	Ps.	—		Ps.	—
Futures		(779,950	)		(1,925,969	)		1,387,177
Crude oil options		(3,771,604	)		—			—
Currency options		5,255,931			(298,789	)		—
Natural gas options		673			(671	)		4,786
Cross-currency swaps		27,747,290			(11,633,605	)		(21,358,898	)
Natural gas swaps		1,780			831			4,355
Propane swaps		—			(3,805	)		(1,136,188	)
Interest rate swaps		(34,306	)		(138,979	)		(351,109	)
Others		(1,105,249	)		—			—
Total	Ps.	25,338,324		Ps.	(14,000,987	)	Ps.	(21,449,877	)

C. Fair value hierarchy

PEMEX values its DFIs under standard methodologies commonly applied in the financial markets. PEMEX’s related assumptions therefore fall under Level 2 of the fair value hierarchy for market participant assumptions, as described below.

The fair values determined by Level 1 inputs utilize quoted prices in financial markets for identical assets or liabilities. Fair values determined by Level 2 inputs are based on quoted prices for similar assets or liabilities in financial markets, and inputs other than quoted prices that are observed for the assets or liabilities. Level 3 inputs are unobservable inputs for the assets or liabilities, and include situations where there is little, if any, market activity for the assets or liabilities.

Management uses appropriate valuation techniques based on the available inputs to measure the fair values of PEMEX’s applicable assets and liabilities.

When available, PEMEX measures fair value using Level 1 inputs, because they generally provide the most reliable evidence of fair value.

The following tables present information about PEMEX’s financial assets and liabilities measured at fair value and indicate the fair value hierarchy of the inputs utilized to determine the fair values as of December 31, 2017 and 2016.

	Fair value hierarchy							Total as of 2017
	Level 1		Level 2			Level 3
Assets:
Derivative financial instruments	Ps.	—	Ps.	30,113,454		Ps.	—	Ps.	30,113,454
Available-for-sale financial assets		—		1,056,918			—		1,056,918
Liabilities:
Derivative financial instruments		—		(17,745,979	)		—		(17,745,979	)
	Fair value hierarchy							Total as of 2016
	Level 1		Level 2			Level 3
Assets:
Derivative financial instruments	Ps.	—	Ps.	4,857,470		Ps.	—	Ps.	4,857,470
Available-for-sale financial assets		6,463,096		2,417,123			—		8,880,219
Liabilities:
Derivative financial instruments		—		(30,867,956	)		—		(30,867,956	)

When market quotes are not available to measure the fair value of PEMEX’s DFIs, PEMEX uses Level 2 inputs to calculate the fair value based on quotes from major market sources. These market quotes are then adjusted internally using standard market pricing models for interest rate, currency, equity and commodities derivatives.

The following table shows the carrying value and the estimated fair value of the remaining financial assets and liabilities, which are not valued at fair value, as of December 31, 2017 and 2016:

	2017				2016
	Carrying value		Fair value		Carrying value		Fair value
Assets:
Cash and cash equivalents	Ps.	97,851,754	Ps.	97,851,754	Ps.	163,532,513	Ps.	163,532,513
Accounts receivable, net		170,645,234		170,645,234		133,220,527		133,220,527
Long-term notes receivable		148,492,909		148,492,909		148,607,602		148,607,602
Liabilities:
Suppliers		139,955,378		139,955,378		151,649,540		151,649,540
Accounts and accrued expenses payable		23,211,401		23,211,401		18,666,607		18,666,607
Short-term debt and current portion of long-term debt		157,209,467		157,209,467		176,166,188		176,166,188
Long-term debt		1,880,665,604		1,996,173,753		1,807,004,542		1,812,109,426

The fair values of the financial current assets and current liabilities presented in the table above are included for informational purposes.

The fair values of current financial assets and short-term liabilities are equal to their nominal values because, due to their short-term maturities, their nominal values are very close to their corresponding fair values.

The fair value of long-term debt is estimated using quotes from major market sources which are then adjusted internally using standard market pricing models. As a result of relevant assumptions, estimated fair values do not necessarily represent the actual terms at which existing transactions could be liquidated or unwound.

The information related to “Cash and cash equivalents”, “Accounts receivable, net”, “Available-for-sale financial assets”, “Long-term notes receivable” and “Debt” is described in the following notes, respectively:

• Note 6, Cash, cash equivalents and restricted cash;

• Note 7, Accounts receivable, net;

• Note 10, Available-for-sale financial assets;

• Note 14, Long-term notes receivable and other; and

• Note 15, Debt.

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Employee Benefits

12 Months Ended

Dec. 31, 2017

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Employee Benefits

NOTE 17. EMPLOYEE BENEFITS

Until December 31, 2015, Petróleos Mexicanos and Subsidiary Entities only had defined benefit pension plans for the retirement of its employees, to which only Petróleos Mexicanos and the Subsidiary Entities contribute. Benefits under these plans are based on an employee’s salary and years of service completed at retirement. As of January 1, 2016, Petróleos Mexicanos and Subsidiary Entities also has a defined contribution pension plan, in which both Petróleos Mexicanos and Subsidiary Entities and the employee contribute to an employee’s individual account.

Benefits under the defined benefit plan are mainly based on the years of service completed by the employee, and their remuneration at the date of retirement. The obligations and costs of these plans are recognized based on an actuarial valuation prepared by independent experts. Within the regulatory framework of plan assets, there are no minimum funding requirements. Petróleos Mexicanos and the Subsidiary Entities have established additional plans to cover post-employment benefits, which are based on actuarial studies prepared by independent experts and which include disability, post-mortem pension and the death of retired employees.

As of December 31, 2017, Petróleos Mexicanos and Subsidiary Entities funded its employees benefits through Mexican trusts, the resources of which come from the retirement line item of PEMEX’s annual budget (an operating expense), or any other line item that substitutes or relates to this line item, or that is associated to the same line item and the interests, dividends or capital gains obtained from the investments of the trusts.

The following table show the amounts associated with PEMEX’s labor obligations:

	December 31,
Defined Benefits Liabilities	2017		2016
Liability for defined benefits at retirement and post-employment at the end of the year		Ps. 1,241,072,307		Ps. 1,202,624,665
Liability for other long-term benefits		17,363,815		17,784,771
Total liability for defined benefits recognized in the consolidated statement of financial position at the end of the year		Ps. 1,258,436,122		Ps. 1,220,409,436

The following tables contain detailed information regarding PEMEX’s retirement and post-employment benefits:

	December 31,
Changes in the liability for defined benefits	2017			2016
Liability for defined benefits at the beginning of the year		Ps. 1,202,624,665			Ps. 1,258,480,019
Recognition of the modifications in pensions plan		8,327			(571,713	)
Current Service cost		13,079,341			23,111,918
Net interest		95,402,917			90,527,624
Past service costs		—			(33,244	)
Defined benefits paid by the fund		(5,105,669	)		(4,892,767	)
Actuarial (gains) losses in other comprehensive results due to:
Change in financial assumptions		47,182,448			(149,533,263	)
Change in demographic assumptions		(70,012,604	)		4,842,109
For experience during the year		10,272,231			36,103,857
In plan assets during the year		(453,206	)		285,123
Remeasurements		26,417			(1,742	)
Contributions paid to the fund		(51,952,560	)		(55,693,256	)
Defined benefit liabilities at end of year		Ps. 1,241,072,307			Ps. 1,202,624,665

In 2017 and 2016, the net actuarial gains recognized in other comprehensive income (loss) net of income deferred tax were Ps. 12,038,710 and Ps. 106,387,640, respectively, related to retirement and post-employment benefits, not including the normal year to year increase in obligations based on changes in population, age, seniority, wages, pensions and benefits. The decrease in losses in 2017 was mainly due to the decrease in the discount and return on plan assets rates, from 8.17% in 2016 to 7.89% in 2017.

	December 31,
Changes in pension plan assets	2017			2016
Plan assets at the beginning of year	Ps.	9,489,666		Ps.	5,228,909
Return on plan assets		902,550			742,477
Payments by the pension fund		(54,312,270	)		(51,889,821	)
Company contributions to the fund(1)		51,952,559			55,693,256
Actuarial (gains) losses in plan assets		453,187			(285,155	)
Pension plan assets at the end of year	Ps.	8,485,692		Ps.	9,489,666

⁽¹⁾  Includes proceeds from the collected amounts of the Promissory Notes, contributed by the Mexican Government (See Note 14).

PEMEX’s plan assets are held in two trusts, the FOLAPE and the Fideicomiso de Cobertura Laboral y de Vivienda (FICOLAVI), which are managed by BBVA Bancomer, S. A. and a technical committee for each trust that is comprised of personnel from Petróleos Mexicanos and the trusts.

The expected contribution to the fund for 2018 amounts to Ps. 63,500,000 and the expected payments for 2018 is Ps. 62,337,560.

As of December 31, 2017 and 2016, the amounts and types of plan assets are as follows:

	December 31,
Plan Assets	2017		2016
Cash and cash equivalents	Ps.	135,757	Ps.	5,906,660
Equity instruments		1,034,178		2,694,291
Debt instruments		7,315,757		888,715
Total plan assets	Ps.	8,485,692	Ps.	9,489,666

	December 31,
Changes in Defined Benefit Obligations (DBO)	2017			2016
Defined benefit obligations at the beginning of the year	Ps.	1,212,114,331		Ps.	1,263,708,928
Service costs		19,762,661			23,107,851
Financing costs		96,331,015			91,270,383
Past service costs					(33,244	)
Payments by the fund		(59,417,940	)		(56,778,359	)
Amount of (gains) and losses recognized through other comprehensive income:		(12,594,541	)		(108,589,515	)
Modifications to the pension plan		(6,609,657	)		(571,713	)
Remeasurements		(1,471	)		—
Reductions		(26,399	)		—
Defined benefit obligations at the end of year	Ps.	1,249,557,999		Ps.	1,212,114,331

The asset ceiling test was not applied because there was a deficit of labor liabilities at the beginning and end of the year.

The effect of an increase or decrease of one percentage point in the discount rate is a -12.46% increase or a 15.72% decrease in defined benefit obligations.

The effect of an increase or decrease of one percentage point in the increase rate in medical services with respect to the cost and obligations related to medical services point is a 21.93% increase or a -16.80% decrease in defined benefit obligations.

Assumptions regarding future mortality are based on EMSSA2009 to Unique Circular of the Comisión Nacional de Seguros y Fianzas (National Commission of Insurance and Bonds) and include changes to the mortality rate established in 2017.

The following tables present additional fair value disclosure about plan assets and indicate their rank, in accordance with IFRS 13, as of December 31, 2017 and 2016:

	Fair value measurements as of December 31, 2017
Plan assets	Quoted prices in active markets for identical assets (level 1)		Significant observable inputs (level 2)		Significant unobservable inputs (level 3)		Total
Cash and cash equivalents	Ps.	135,757	Ps.	—	Ps.	—	Ps.	135,757
Equity instruments		1,034,178		—		—		1,034,178
Debt instruments		7,315,757		—		—		7,315,757
Total	Ps.	8,485,692	Ps.	—	Ps.	—	Ps.	8,485,692

	Fair value measurements as of December 31, 2016
Plan assets:	Quoted prices in active markets for identical assets (level 1)		Significant observable inputs (level 2)		Significant unobservable inputs (level 3)		Total
Cash and cash equivalents	Ps.	5,906,660	Ps.	—	Ps.	—	Ps.	5,906,660
Equity instruments		2,694,291		—		—		2,694,291
Debt instruments		888,715		—		—		888,715
Total	Ps.	9,489,666	Ps.	—	Ps.	—	Ps.	9,489,666

As of December 31, 2017 and 2016, the principal actuarial assumptions used in determining the defined benefit obligation for the plans are as follows:

	December 31,
	2017			2016
Rate of increase in salaries		4.77	%		4.77	%
Rate of increase in pensions		3.75	%		3.75	%
Rate of increase in medical services		7.65	%		7.65	%
Inflation assumption		3.75	%		3.75	%
Discount and return on plan assets rate		7.89	%		8.17	%
Average length of obligation (years)		18.40			17.67

In accordance with IAS 19, the discount rate used is determined by considering the government zero coupon curve generated from the fixed rate bonds issued by the Mexican Government (“Bonds M”) and Cetes, as well as the flow of payments expected to cover contingent liabilities.

Other long-term benefits

Petróleos Mexicanos and Subsidiary Entities has established other long-term benefit plans for its employees, to which employees do not contribute, which correspond to the seniority premiums payable for disability, death and survivors benefits (payable to the widow and beneficiaries of worker), medical service, gas and basic basket for beneficiaries. Benefits under these plans are based on an employee’s salary and years of service completed at separation date. Obligations and costs of such plans are recorded in accordance with actuarial valuations performed by independent actuaries.

The amounts recognized for long-term obligations for the years ended December 31, 2017 and 2016 are as follows:

	December 31,
Change in the liability for defined benefits	2017			2016
Liabilities defined benefit at the beginning of year	Ps.	17,784,771		Ps.	20,905,422
Charge to income for the year		3,277,847			3,420,158
Actuarial (gains) losses recognized in income due to:
Change in financial assumptions		878,516			(3,028,211	)
Change in demographic assumptions		(1,015,274	)		(119,982	)
For experience during the year		(3,558,599	)		(3,390,396	)
Benefits paid		(3,446	)		(2,220	)
Liabilities defined benefit at the end of year	Ps.	17,363,815		Ps.	17,784,771

The principal actuarial assumptions used in determining the defined benefit obligation for the plans are as follows:

	December 31,
	2017			2016
Rate of increase in salaries		4.77	%		4.77	%
Inflation assumption		3.75	%		3.75	%
Discount and return on plan assets rate		7.89	%		8.17	%
Average length of obligation (years)		18.40			17.67

In accordance with IAS 19, the discount rate used is determined by considering the government zero coupon curve generated from Bonds M and Cetes, as well as the flow of payments expected to cover contingent liabilities.

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Provisions for Sundry Creditors

12 Months Ended

Dec. 31, 2017

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Provisions for Sundry Creditors

NOTE 18. PROVISIONS FOR SUNDRY CREDITORS

At December 31, 2017 and 2016, the provisions for sundry creditors and others is as follows:

	2017		2016
Provision for plugging of wells (Note 12)	Ps.	68,797,600	Ps.	64,967,710
Provision for trails in process (Note 25)		7,812,689		15,119,692
Provision for environmental costs		11,067,134		8,230,476
	Ps.	87,677,423	Ps.	88,317,878

The following tables show the allowance account for plugging of wells, trials in progress and environmental costs:

	Plugging of wells
	2017			2016
Balance at the beginning of the year	Ps.	64,967,710		Ps.	56,894,695
Decrease capitalized in fixed assets		(3,791,482	)		(3,878,503	)
Unwinding of discount against income		7,774,000			11,968,966
Amount used		(152,628	)		(17,448	)
Balance at the end of the year	Ps.	68,797,600		Ps.	64,967,710

	Trials in progress
	2017			2016
Balance at the beginning of the year	Ps.	15,119,692		Ps.	12,775,263
Additions against income		2,835,357			3,049,202
Provision cancellation		(1,973,153	)		(632,806	)
Amount used		(8,169,207	)		(71,967	)
Balance at the end of the year	Ps.	7,812,689		Ps.	15,119,692

	Environmental costs
	2017			2016
Balance at the beginning of the year	Ps.	8,230,476		Ps.	3,521,838
Additions against income		3,203,982			6,118,454
Provision cancellation		(312,937	)		(1,347,285	)
Amount used		(54,387	)		(62,531	)
Balance at the end of the year(1)	Ps.	11,067,134		Ps.	8,230,476

(1) PEMEX is subject to the provisions of the Ley General del Equilibrio Ecológico y la Protección al Ambiente (General Law on Ecological Equilibrium and Environmental Protection). To comply with this law, environmental audits of PEMEX’s larger operating, storage and transportation facilities have been or are being conducted. Following the completion of such audits, PEMEX has signed various agreements with the Procuraduría Federal de Protección al Ambiente (Federal Attorney of Environmental Protection) to implement environmental remediation and improve environmental plans. Such plans contemplate remediation for environmental damages, as well as related investments for the improvement of equipment, maintenance, labor and materials.

Provision for plugging of wells

PEMEX records a provision at present value for the future plugging cost of an oil production facility or pipeline at the time that it is built. Present value is determined based on discount rates ranging from 4.0% to 10.5% in 2017.

The plugging provision represents the present value of plugging costs related to oil and gas properties. These provisions have been created based on internal estimates of PEMEX. PEMEX has made certain assumptions based on the current economic environment that PEMEX believes provide a reasonable basis on which to estimate the future liability. These estimates are reviewed regularly to take into account any material changes in the assumptions. However, actual plugging costs in the long run will depend on future market prices for the necessary plugging work, which reflect market conditions at the time the work is being performed.

Moreover, the time of plugging depends on when the fields cease to have economically viable production rates, which, in turn, depends on the inherently uncertain future prices of oil and gas.

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Disclosures of Cash Flow

12 Months Ended

Dec. 31, 2017

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Disclosures of Cash Flow

NOTE 19. DISCLOSURES OF CASH FLOW

The following items represent non-cash transactions and are presented for disclosure purposes:

	For the years ended December 31,
	2017			2016		2015
Operating activities
Employee benefits equity effect(i)		Ps. 12,038,710			Ps. 106,277,761		Ps. 78,556,569
Net (benefits) cost of the year for employee benefits(i)		108,073,074			109,738,416		(62,549,142	)
Investing activities(ii)
Available-for-sale financial assets		5,564,130			207,817		(3,206,316	)
Financing activities
Financed Public Works Contracts		—			146,217,292		2,001,093
Currency translation effect		(7,597,283	)		21,386,902		13,262,101
Accrued interest		8,734,131			9,326,945		4,816,784

(i) Items that do not impact cash flows but that reflect the actuarial valuation at the end of the year.

(ii) Non-cash investing transactions are included in Note 12-d.

Material changes in liabilities from financing activities are disclosed in Note 15.

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Income Taxes and Federal Duties

12 Months Ended

Dec. 31, 2017

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Income Taxes and Federal Duties

NOTE 20. INCOME TAXES AND FEDERAL DUTIES

The Ley de Ingresos sobre Hidrocarburos (“Hydrocarbons Revenue Law”) was published in the Official Gazette of the Federation on August 11, 2014, and came into effect, on January 1, 2015. The Hydrocarbons Revenue Law sets forth the new fiscal regime for Petróleos Mexicanos applicable to the assignments and the contracts that were established on such date. Likewise, every year the Federal Revenue Law is published in the Official Gazette of the Federation and includes specific regulations for Petroleos Mexicanos and the Subsidiary Entities.

Tax regime applicable to Assignments

The tax regime applicable to the exploration and production for the assignments granted to PEMEX by the Mexican Government includes the following taxes and duties:

a. Derecho por la Utilidad Compartida “DUC” (Profit-sharing Duty).

As of January 1, 2015, Pemex Exploration and Production is obligated to pay a Profit-sharing Duty.

As of January 1, 2017 and 2016, the applicable rate of this duty was 67.50% and 68.75% respectively. The computation of this duty is based on the excess of the value of hydrocarbons produced during the fiscal year (including self-consumption, shrinkage and burning), minus certain permitted deductions by the Hydrocarbons Revenue Law, including part of the investments and some costs, expenses and duties. Pursuant to the Hydrocarbons Revenue Law, this duty decreases on an annual basis. As of January 1, 2019, this duty will be set at 65%.

During 2017, this duty totaled Ps. 372,902,629 from annual payments presented on March 31, 2018 paid as follows: Ps. 377,192,377, in monthly installment payments and a favorable balance amounting to Ps. 4,289,748, presented in accounts receivable, net line item in the statement of financial position.

During 2016, this duty totaled Ps. 304,299,019 from annual payments presented on April 3, 2017 paid as follows: Ps. 301,050,325, in monthly installment payments and a payable balance amounting to Ps. 3,248,694.

The accounting result differs from the tax result mainly due to differences in depreciation, non-deductible expenses and others. Such differences generate a deferred DUC.

Total DUC and other as of December 31, 2017 and 2016 are integrated as follows:

	2017			2016
DUC	Ps.	372,902,629		Ps.	304,299,019
DUC from prior years		2,095,429			—
Other		260,775			514,356
Deferred DUC benefit		(37,214,624	)		(27,651,571	)
Total DUC and other	Ps.	338,044,209		Ps.	277,161,804

The principal factors generating the deferred DUC are the following:

	2017			2016
Deferred DUC asset:
Provisions	Ps.	541,360,940		Ps.	570,544,863
Total deferred DUC asset		541,360,940			570,544,863
Deferred Profit-sharing duty liability:
Wells, pipelines, properties, plant and equipment		(455,697,786	)		(473,406,721	)
Deferred DUC liability		(455,697,786	)		(473,406,721	)
Deferred asset net		85,663,154			97,138,142
Valuation reserve(1)		(20,796,959	)		(69,486,571	)
Net, deferred DUC asset	Ps.	64,866,195		Ps.	27,651,571
(1)   PEMEX added to its valuation reserve since it estimates that some allowed deductions will not materialize in future years.

The expected expense for DUC is different from that which would result from applying the 65% rate to the tax base, as a result of the items mentioned below:

	2017			2016
Expected expense:		Ps. 127,436,912			Ps. 159,897,683
Increase (decrease) resulting from:
Non-cumulative profit		(514,780,219	)		(423,761,673	)
Non-deductible expenses		387,343,306			263,863,990
Production value		518,433,469			441,655,000
Deductible duties		(39,503,110	)		(29,918,201	)
Deferred DUC reserve		(48,689,612	)		69,486,571
Deductions cap		(94,552,741	)		(204,575,922	)
DUC from prior years		2,095,429			—
Other		260,775			514,356
DUC-Profit-sharing duty expense		Ps. 338,044,209			Ps. 277,161,804

On August 18, 2017, the Official Gazette of the Federation published a decree, granting tax benefits for extraction activities in assignments with mature and / or marginal fields, substantially increasing the percentage of costs, expenses and investments that PEMEX could deduct for purposes of calculating the DUC. As a result, PEMEX received a tax benefit of Ps. 7,769,915.

On November 30, 2017, the Acuerdo por el que se reforman y adicionan diversas disposiciones de las Reglas de carácter general para definir los métodos de ajuste del valor de los hidrocarburos de los derechos sobre hidrocarburos (Agreement by which various provisions of the general rules are reformed and added to define the methods of adjusting the value of hydrocarbons and hydrocarbon rights)was published in the Official Gazette of the Federation, resulting in new calibrations and adjustments of existing formulas of calculating the value of hydrocarbons and hydrocarbon rights. As a result, PEMEX received an estimated tax benefit of Ps. 8,854,391.

The compensation of Ps. 2,186,963 was also authorized for the recognition of the fair economic value of the investments affected as a result of the allocation process for assignments to carry out hydrocarbon exploration and extraction activities, in accordance with the provisions of Transitory Article 21 of the Federation Income Law of 2017.

On April 18, 2016, a decree granting a fiscal benefit to Pemex Exploration and Production (assignee) was published in the Official Gazette of the Federation and increases the limit on the amount Pemex Exploration and Production can deduct for costs, expenses and investments in the calculation of its DUC, for onshore areas or in offshore areas with water depths lower than 500 meters. The benefit was granted to further the Mexican Government’s strategic hydrocarbon exploration and extraction activities through assignments, in light of historically low international hydrocarbons prices in late 2015 and early 2016 combined with historically low oil production in Mexico, thereby, together with other actions avoiding that the worldwide economic conditions had affected the national economy. The benefit obtained was Ps. 40,213,913. Additionally, the Mexican Government granted PEMEX a fiscal support on November 16, 2016 of Ps. 28,439,379. This benefit consisted of a tax credit against the DUC as a measure to mitigate the impact generated by the financial environment of the Mexican hydrocarbons exploration and extraction companies (assignees), as international energy prices continued to be depressed, which impacted the economies of several countries, including Mexico.

b. Derecho de Extracción de Hidrocarburos (Hydrocarbons Extraction Duty).

This duty is to be calculated using a rate based on a formula applicable to each type of hydrocarbon, the volume of production and utilizing the relevant market price for hydrocarbons in U.S. Dollars.

During 2017 Pemex Exploration and Production made payments of Ps. 58,523,125, which are included in the cost of sales line item.

c. Derecho de Exploración de Hidrocarburos (Exploration Hydrocarbons Duty).

The Mexican Government is entitled to collect a monthly payment of Ps. 1,214.21 per square kilometer of non-producing areas. After 60 months, this tax increases to Ps. 2,903.54 per square kilometer for each additional month that the area is not producing. These amounts will be updated on an annual basis in accordance with the national consumer price index.

During 2017, Pemex Exploration and Production made payments under this duty, totaling Ps. 980,843, which are included in the cost of sales line item.

d. Impuesto por la actividad de Exploración y Extracción de Hidrocarburos (Exploration and Extraction Hydrocarbons Duty).

The assignments granted by the Mexican Government create a tax on the exploration and extraction activities carried out in the corresponding area. The monthly tax paid during the exploration phase and until the extraction phase begins is Ps. 1,583.74 per square kilometer. During the extraction phase, the monthly tax from the start of the extraction phase and until the assignment ends is Ps. 6,334.98 per square kilometer. During 2017 payments for this tax amounted Ps. 3,986,112, which are included in the cost of sales line item.

Tax Regime applicable to contracts:

As of January 1, 2015, the tax regime applicable to Pemex Exploration and Production for contracts is set forth in the Hydrocarbons Revenue law which regulates, among other things, the fiscal terms applicable to the exploration and extraction contracts (license, profit sharing contracts, production sharing and services) and sets duties and other taxes paid to the Mexican Government.

The Hydrocarbons Revenue Law also establishes the following duties applicable to PEMEX in connection with assignments granted to it by the Mexican Government:

• Cuota Contractual para la Fase Exploratoria (Exploration Phase Contractual Fee)

During the exploration phase of an exploration and extraction contract, the Mexican Government is entitled to collect a monthly payment of Ps. 1,175.42 per square kilometer of non-producing areas. After 60 months, this fee increases to Ps. 2,810.78 per square kilometer for each additional month that the area is not producing. The fee amount will be updated on an annual basis in accordance with the national consumer price index.

• Regalías (Royalties)

Royalty payments to the Mexican Government are determined based on the “contractual value” of the relevant hydrocarbons, which is based on a variety of factors, including the type of underlying hydrocarbons (e.g., crude oil, associated natural gas, non-associatednatural gas or condensates), the volume of production and the market price. Royalties are payable in connection with licensing contracts, production-sharing contracts and profit-sharing contracts.

• Pago del Valor Contractual (Contractual Value Payment)

Licensing contracts require a payment to the Mexican Government calculated as a percentage of the “contractual value” of the hydrocarbons produced, as determined by the SHCP on a contract-by-contract basis.

• Porcentaje a la Utilidad Operativa (Operating Profit Payment)

Production-sharing contracts and profit-sharing contracts require a payment equivalent to a specified percentage of operating profits. In the case of production-sharing contracts, this payment shall be made in-kind through delivery of the hydrocarbons produced. In the case of profit-sharing contracts, this payment shall be made in cash.

• Bono a la Firma (Signing Bonus)

Upon execution of a licensing contract, a signing bonus is to be paid to the Mexican Government in an amount specified by the SHCP in the relevant bidding terms and conditions or in the contracts resulting from a migration.

• Impuesto por la actividad de Exploración y Extracción de Hidrocarburos (Hydrocarbons Exploration and Extraction Activities Tax)

Contracts for exploration and extraction granted by the Mexican Government will include a specified tax on the exploration and extraction activities carried out in the relevant area. A monthly tax of Ps. 1,583.74 per square kilometer is payable during the exploration phase until the extraction phase begins. During the extraction phase of a project, a monthly tax of Ps. 6,334.98 per square kilometer is payable from the starting date until the relevant contract for exploration and extraction is terminated.

Other applicable taxes

Beginning with the creation of the Subsidiary Entities during 2015, they became subject to the Income Tax Law and the Value Added Tax Law. Pemex Industrial Transformation is also subject to the Special Tax on Production and Services (IEPS Tax).

2017 indirect taxes are as listed below:

a. IEPS Tax

IEPS Tax on the sale of automotive fuels: This is a tax imposed on domestic sales of automotive fuels, including gasoline and diesel, which Pemex Industrial Transformation collects on behalf of the Mexican Government. The applicable quotas for 2017 were: 4.30 pesos per liter of Magna gasoline; 3.64 pesos per liter of Premium gasoline and 4.73 pesos per liter of diesel. This fee is updated annually according to inflation and adjusted monthly by the tax authorities.

IEPS Tax to benefit Mexican states and municipalities: This tax is a quota on domestic sales of automotive fuels, including gasoline and diesel, which Pemex Industrial Transformation collects on behalf of the Mexican Government. The applicable quotas for 2017 were 38.00 cents per liter of Magna gasoline, 46.37 cents per liter of premium gasoline and 31.54 cents per liter of diesel. This rate is updated annually with inflation. The funds raised by this quota are allocated to the states and municipalities as provided in the Tax Coordination Law.

IEPS Tax on Fossil Fuels: This tax is a quota on the internal sales of fossil fuels, which Pemex Industrial Transformation collects on behalf of the Mexican Government. The applicable quotas for 2017 were 6.50 cents per liter for propane, 8.42 cents per liter for butane, 11.41 cents per liter for jet and other fuel, 13.64 cents per liter for turbosine and other kerosene, 13.84 cents per liter for diesel, 14.78 cents per liter for fuel oil and Ps. 17.15 per ton for petroleum coke. This rate is updated annually according to inflation.

b. Value Added Tax (“VAT”)

For VAT purposes, final monthly payments are determined based on PEMEX’s cash flow, in accordance with the provisions of the Value Added Tax Law, applicable to payers of this tax.

The VAT is caused by the sales of goods, rendering of services, granting of the temporary use of goods in the national territory and by the importation of goods and services to the national territory. VAT taxpayers transfer VAT to their customers and are entitled to credit the VAT paid to their suppliers and on their imports. The net balance between VAT transferred to customers and paid to suppliers and on imports results each month in the VAT to be paid to the tax authorities or in an amount in favor of the taxpayer. The taxpayer has the right to credit VAT in favor against VAT payable in future months, to request a refund or to offset it against other payable federal taxes.

Taxes on Income are described below:

c. Income Tax

As of January 1, 2015, Petróleos Mexicanos, Subsidiary Entities and the subsidiary companies residing in Mexico for tax purposes are subject to the Income Tax Law.

This tax is calculated by applying a rate of 30% to the tax result. Tax result is the excess of total revenues over the allowed deductions and tax losses from previous years.

Accounting income differs from taxable income primarily due to the effects of inflation and differences between depreciation and other non-deductible expenses.

For the years ended December 31, 2017, 2016 and 2015, Petroleos Mexicanos and its Subsidiary Companies incurred the following income tax expense (benefit):

	2017			2016			2015
Current income tax	Ps.	3,546,912		Ps.	6,201,842		Ps.	7,426,892
Deferred income tax		(9,334,064	)		(18,842,211	)		(53,014,159	)
Total	Ps.	(5,787,152	)	Ps.	(12,640,369	)	Ps.	(45,587,267	)
Income tax REFIPRE (Preferent Fiscal Regime)	Ps.	722,984		Ps.	—		Ps.	—

The principal factors generating the deferred income tax are the following:

	2016			Recognized in profit and loss			Recognized in OCI			2017
Deferred income tax asset:
Provisions	Ps.	5,906,581		Ps.	2,393,237		Ps.	—		Ps.	8,299,818
Employee benefits provision		125,973,332			4,902,275			(800,284	)		130,075,323
Advance payments from clients		1,046,010			1,728,296			—			2,774,306
Accrued liabilities		2,269,561			(1,897,574	)		—			371,987
Non-recoverable accounts receivable		778,179			(38,431	)		—			739,748
Derivative financial instruments		223,518			(144,263	)		—			79,255
Wells, pipelines, properties and equipment		458,273,897			(52,834,079	)		—			405,439,818
Tax loss carryforwards(1)		43,327,737			(9,216,777	)		—			34,110,960
Total deferred income tax asset		637,798,815			(55,107,316	)		(800,284	)		581,891,215
Valuation reserve(2)		(565,125,697	)		64,560,772			—			(500,564,925	)
Net deferred income tax asset		72,673,118			9,453,456			(800,284	)		81,326,290
Deferred income tax liability:
Wells, pipelines, properties, plant and equipment		(3,632,294	)		188,676			—			(3,443,618	)
Other		(502,242	)		(308,068	)		—			(810,310	)
Total deferred income tax liability		(4,134,536	)		(119,392	)		—			(4,253,928	)
Net long-term deferred income tax liability	Ps.	68,538,582		Ps.	9,334,064		Ps.	(800,284	)	Ps.	77,072,362

	2015			Recognized in profit and loss			Recognized in OCI and equity (3)			2016
Deferred income tax asset:
Provisions	Ps.	25,414,822		Ps.	(19,508,241	)	Ps.	—		Ps.	5,906,581
Employee benefits provision		247,834,882			(119,837,137	)		(2,024,413	)		125,973,332
Advance payments from clients		1,015,357			30,653			—			1,046,010
Accrued liabilities		1,514			2,268,047			—			2,269,561
Non-recoverable accounts receivable		104,346			673,833			—			778,179
Derivative financial instruments		22,506			201,012			—			223,518
Wells, pipelines, properties and equipment		446,970,333			11,303,564			—			458,273,897
Tax loss carryforwards(1)		14,894,231			28,433,506			—			43,327,737
Total deferred income tax asset		736,257,991			(96,434,763	)		(2,024,413	)		637,798,815
Valuation reserve(2)		(681,357,607	)		116,231,910			—			(565,125,697	)
Net deferred income tax asset		54,900,384			19,797,147			(2,024,413	)		72,673,118
Deferred income tax liability:
Wells, pipelines, properties, plant and equipment		(1,909,529	)		(726,999	)		(995,766	)		(3,632,294	)
Other		(274,305	)		(227,937	)		—			(502,242	)
Total deferred income tax liability		(2,183,834	)		(954,936	)		(995,766	)		(4,134,536	)
Net long-term deferred income tax liability	Ps.	52,716,550		Ps.	18,842,211		Ps.	(3,020,179	)	Ps.	68,538,582

(1) Tax loss carryforwards expire in 2027.

(2) Due to PEMEX’s estimate that not enough taxable income will be generated in future periods, a valuation reserve was recognized to account for the deferred income tax asset.

(3) Includes effects from business combination in equity of Ps. (995,766).

Expense attributable to the profit (loss) from continuing operations before income taxes was different from that which would result from applying the 30% rate to profit, as a result of the items listed below:

	For the years ended December 31,
	2017			2016			2015
Expected income tax expense	Ps.	(20,055,588	)	Ps.	(14,901,324	)	Ps.	(3,089,241	)
Increase (decrease) resulting from:
Tax effect of inflation-net		14,302,118			8,098,213			(1,618,327	)
Difference between accounting and tax depreciation		(3,713,920	)		(1,765,183	)		(107,231	)
Non-deductible expenses		1,954,659			1,558,120			(1,921,515	)
Others-net		(1,725,579	)		(5,630,195	)		(38,850,953	)
Income tax expense	Ps.	(5,787,152	)	Ps.	(12,640,369	)	Ps.	(45,587,267	)

As of December 31, 2017 and 2016, the net accumulated effect of actuarial gains and losses on deferred tax was Ps. 17,688,032 and Ps. 16,887,748, respectively. In addition, as of December 31, 2017 and 2016, the deferred tax effect of actuarial gains and losses from Petróleos Mexicanos and PMI CIM are presented in comprehensive (loss) income in the amounts of Ps. (800,284) and Ps. (2,024,413), respectively. As of December 31, 2015, the deferred tax effect of PMI CIM’s performance was Ps. (124,285).

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Equity (Deficit), Net

12 Months Ended

Dec. 31, 2017

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Equity (Deficit), Net

NOTE 21. EQUITY (DEFICIT), NET

a. Certificates of Contribution “A”

The capitalization agreement between Petróleos Mexicanos and the Mexican Government states that the Certificates of Contribution “A” constitute permanent capital.

On January 19, 2015, the Mexican Government made an equity contribution of Ps. 10,000,000 to Petróleos Mexicanos in accordance with the Ley Federal del Presupuesto y Responsabilidad Hacendaria (Federal Law of Budget and Fiscal Accountability).

On December 24, 2015, the Mexican Government, through the SHCP, issued a non-negotiable promissory note of Ps. 50,000,000 due December 31, 2050 for the assumption by the Mexican Government of the payment obligations related to pensions and retirement plans of Petróleos Mexicanos and its Subsidiary Entities (see Note 14).

On April 21, 2016, the Mexican Government made an equity contribution to Petróleos Mexicanos in the amount of Ps. 26,500,000 following the guidelines established in the Federal Budget and Fiscal Responsibility. This contribution was recognized as an increase in Certificates of Contribution “A.”

On August 3, 2016, the Mexican Government issued Ps. 184,230,586 in exchange for the Ps. 50,000,000 non-negotiable promissory note issued to Petróleos Mexicanos on December 24, 2015, which was recognized as a Ps. 135,439,612 increase in equity. The Ps. 135,439,612 increase in equity was the result of the Ps. 184,230,586 value of the promissory notes as of June 29, 2016, minus the Ps. 50,000,000 promissory note received by Petróleos Mexicanos on December 24, 2015, plus a Ps. 1,209,026 increase in the value of the promissory notes from June 29, 2016 to August 15, 2016, the date on which Petróleos Mexicanos received the promissory notes (see Note 14).

PEMEX’s permanent equity is as follows:

	Amount
Certificates of Contribution “A” as of December 31, 2015	Ps.	194,604,835
Increase in Certificates of Contribution “A” during 2016		161,939,612
Certificates of Contribution “A” as of December 31, 2016		356,544,447
Increase in Certificates of Contribution “A” during 2017		—
Certificates of Contribution “A” as of December 31, 2017	Ps.	356,544,447

b. Mexican Government contributions

As of December 31, 2017 and 2016 there were no Mexican Government contributions.

c. Legal reserve

Under Mexican law, each of the Subsidiary Companies is required to allocate a certain percentage of its net income to a legal reserve fund until the fund reaches an amount equal to a certain percentage of each Subsidiary Company’s capital stock.

As of December 31, 2017 and 2016, there were no changes to the legal reserve.

d. Accumulated deficit from prior years

PEMEX has recorded negative earnings in the past several years. However, the Ley de Concursos Mercantiles (“Commercial Bankruptcy Law of Mexico”) is not applicable to Petróleos Mexicanos and the Subsidiary Entities. Furthermore, the financing agreements to which PEMEX is a party do not provide for financial covenants that would be breached or events of default that would be triggered as a consequence of negative equity (see Note 2-b). The Mexican Government has focused its recent efforts on consolidating PEMEX’s institutional strategy, including the approval of amendments to the Mexican Constitution published as the Energy Reform Decree on December 20, 2013, which permit it greater autonomy in decision-making and enhanced operational viability (see Note 1).

e. Non-controlling interest

Effective July 1, 2005, PEMEX entered into an option agreement with BNP Private Bank & Trust Cayman Limited; the option was not exercised and was terminated on July 20, 2015. On July 1, 2015, PEMEX also entered into a new option agreement with SML Trustees Limited to acquire 100% of the shares of Pemex Finance, Ltd, which allows PEMEX to have control over Pemex Finance Ltd. because of the potential voting rights. As of the date of these consolidated financial statements the option agreement has not been exercised. As a result, the financial results of Pemex Finance, Ltd. are included in these consolidated financial statements of PEMEX. Under IFRS, variations in income and equity from Pemex Finance, Ltd. are presented in the consolidated statements of changes in equity (deficit), net as “non-controlling interest,” and as net income and comprehensive income for the year, attributable to non-controlling interest, in the consolidated statements of comprehensive income, due to the fact that PEMEX does not currently own any of the shares of Pemex Finance, Ltd.

Similarly, because PEMEX does not currently own all of the shares of PMI CIM, HJ BARRERAS and COMESA, variations in income and equity from these entities are also presented in the consolidated statements of changes in equity (deficit) as “non-controlling interest.”

As of December 31, 2017 and 2016, non-controlling interest represented gains of Ps. 965,107 and Ps. 976,705, respectively, in PEMEX’s equity (deficit).

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Oher Revenues and Expenses - Net

12 Months Ended

Dec. 31, 2017

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Oher Revenues and Expenses - Net

NOTE 22. OTHER REVENUES AND EXPENSES-NET

Other revenues and expenses-net for each of the years ended December 31, 2017, 2016 and 2015, was as follows:

	2017			2016			2015
Revenues:
Claims recovery	Ps.	16,386,250		Ps.	3,695,217		Ps.	1,975,281
Fiscal support (Profit-sharing duty) (see Note 20a.)		—			28,439,379			—
Other income for services		4,720,546			4,266,854			3,953,888
Price of sale share (see Note 11-iii)		3,139,103			22,684,736			—
Other		4,277,207			14,228,801			6,992,954
Revenues from reinsurance premiums		1,986,568			3,694,026			1,497,779
Franchise fees		917,934			1,059,333			1,148,528
Bidding terms, sanctions, penalties and other		825,956			3,223,437			1,262,458
Gain on sale of fixed assets		—			2,687,652			—
Assets value transferred to CENAGAS		—			7,450,931			—
Negative IEPS		—			—			2,519,126
Total other revenues		32,253,564			91,430,366			19,350,014
Expenses:
Loss in the Assets value transferred to CENAGAS		—			(35,333,411	)		—
Disposal of assets		(8,447,031	)		(2,140,943	)		(3,364,063	)
Transportation and distribution of natural gas		(6,652,878	)		(8,830,967	)		(369,317	)
Other		(7,927,150	)		(3,581,036	)		(726,589	)
Claims		(3,640,036	)		(4,757,116	)		(12,527,548	)
Loss in the sale of associates		(412,393	)		(7,473,698	)		—
Impairment of goodwill		—			(4,007,018	)		—
Services provided		—			(2,656,571	)		(3,237,984	)
Total other expenses		(27,079,488	)		(68,780,760	)		(20,225,501	)
Other revenues and expenses-net	Ps.	5,174,076		Ps.	22,649,606		Ps.	(875,487	)

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Related Parties

12 Months Ended

Dec. 31, 2017

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Related Parties

NOTE 23. RELATED PARTIES

Directors and employees of Petróleos Mexicanos and the Subsidiary Entities are subject to regulations related conflict of interest such as the Petróleos Mexicanos Law, Ley Federal de Responsabilidades Administrativas de los Servidores Públicos (Federal Law of Administrative Responsibilities of Public Officials) and the Políticas y Lineamientos Anticorrupción para Petróleos Mexicanos, sus Empresas Productivas Subsidiarias y, en su caso, Empresas Filiales (Anticorruption Policies and Guidelines for Petróleos Mexicanos, its Subsidiary Productive Companies and, where applicable, Subsidiary Companies). Under these provisions, PEMEX’s directors and employees are obligated to “recuse themselves from intervening in any way in the attention to, processing or resolution of matters in which they might have personal, family or business interest, including those where some benefit can result for themselves, their spouse, blood or affinity relatives up to the fourth degree, or civil relatives, or for third parties with which they have professional, labor or business relations, or for partners or partnerships where the public officials or the persons referred above are or have been members thereof.”

Related parties include individuals and companies that do not form part of PEMEX, but that could take advantage of being in a privileged position as a result of their relation with PEMEX. Also included are situations in which PEMEX could take advantage of a special relationship in order to benefit its financial position or results of operations.

Secretary of Energy, Mr. Pedro Joaquín Coldwell, Chairman of the Board of Directors of Petróleos Mexicanos since December 2012, as well as certain members of his family, have held ownership interests since prior to Mr. Pedro Joaquín Coldwell’s appointment to the Board of Directors and through October of 2017 in companies that have entered into agreements with Pemex-Refining, which are now obligations of Pemex Industrial Transformation, for the sale and purchase of gasoline and other products by certain retail service stations and a wholesale distributor, as well as the performance of other related activities, as provided below:

Company	Name	Ownership share
Servicio Cozumel, S. A. de C. V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1)		60	%
	Mr. Pedro Oscar Joaquín Delbouis (son of Mr. Joaquín Coldwell)		20	%
	Mr. Nassim Joaquín Delbouis (son of Mr. Joaquín Coldwell)		20	%
Planta de Combustible Cozumel, S. A. de C. V. (which operates as a wholesale distributor)	Fideicomiso Testamentario(2)		57	%
	Mr. Pedro Joaquín Coldwell(1)		40	%
Gasolinera y Servicios Juárez, S. A. de C. V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1)		40	%
	Fideicomiso Testamentario(3)		40	%
	Mr. Ignacio Nassim Ruiz Joaquín (nephew of Mr. Joaquín Coldwell)		20	%
Combustibles Caleta, S. A. de C. V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1)		20	%
	Mr. Pedro Oscar Joaquín Delbouis		20	%
	Mr. Nassim Joaquín Delbouis		20	%
	Fideicomiso Testamentario(4)		20	%
	Mr. Ignacio Nassim Ruiz Joaquín		20	%
Combustibles San Miguel, S. A. de C. V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1)		25	%
	Mr. Pedro Oscar Joaquín Delbouis		25	%
	Mr. Nassim Joaquín Delbouis		25	%
	Mr. Ignacio Nassim Ruiz Joaquín		25	%

(1) In November, 2017, Mr. Pedro Joaquín Coldwell transmitted all of his shares in these companies to a management and investment trust held at Banco Mercantil del Norte, S.A., Institución de Banca Múltiple, Grupo Financiero Banorte.

(2) 60% of these shares were owned by Fausto Nassim Joaquín Ibarra (father of Pedro Joaquín Coldwell), until his death in June of 2016, after which 57% of these shares became property of an investment, management and testamentary revocable trust, which is referred to as the Testamentary Trust. 50% of the voting rights of these shares are currently exercised by Mr. Pedro Oscar Joaquín Delbouis, and 50% are exercised by Mr. Nassim Joaquín Delbouis.

(3) 40% of these shares were owned by Fausto Nassim Joaquín Ibarra until his death in June of 2016, after which these shares became property of the Testamentary Trust. 100% of the voting rights of these shares are currently exercised by Mr. Pedro Joaquín Coldwell.

(4) 20% of these shares were owned by Fausto Nassim Joaquín Ibarra until his death in June of 2016, after which these shares became property of the Testamentary Trust. 50% of the voting rights of these shares are currently exercised by Mr. Pedro Oscar Joaquín Delbouis, and 50% are exercised by Mr. Nassim Joaquín Delbouis.

The rights of these companies to operate retail service stations and distribute gasoline and other products on a wholesale basis in Mexico are dependent on these agreements, the expiration or non-renewal of which may adversely affect their business. These agreements are based on PEMEX’s standard forms of agreements and contain the standard terms and conditions applicable to all of Pemex Industrial Transformation’s retail service stations and wholesale distributors.

a. Compensation of Directors and Officers

For the years ended December 31, 2017, 2016 and 2015, the aggregate compensation of executive officers of Petróleos Mexicanos and the Subsidiary Entities paid or accrued in that year for services in all capacities was approximately Ps. 50,749, Ps. 49,165 and Ps. 116,930, respectively. Retirement and former employee benefits are granted as described in Note 17. Except in the case of the professional members, with respect to the previous Board of Directors of Petróleos Mexicanos and the boards of directors of the existing Subsidiary Entities, and the independent members, with respect to the new Board of Directors of Petróleos Mexicanos, members of the Boards of Directors of Petróleos Mexicanos and the Subsidiary Entities do not receive compensation for their services.

The compensation paid or accrued during 2017, 2016 and 2015 to the professional members of the previous Board of Directors of Petróleos Mexicanos and boards of directors of the existing Subsidiary Entities was approximately Ps. 7,525, Ps. 8,339, and Ps. 17,899, respectively.

b. Salary Advances

As an employee benefit, PEMEX offers salary advances to all of its eligible Petroleum Workers’ Union and non-union workers, including executive officers, pursuant to the programs set forth in the collective bargaining agreement and in the Reglamento de Trabajo del Personal de Confianza de Petróleos Mexicanos y Empresas Productivas Subsidiarias (Employment Regulation of White Collar Employees of Petróleos Mexicanos and Subsidiary Entities), respectively. The salary advances, which are non-interest bearing, are offered to each eligible employee in an amount up to a maximum of four months’ salary and are repaid through salary deductions in equal installments over a period of either one or two years, as elected by the employee. Most employees take advantage of this benefit. The amount of salary advances outstanding to executive officers at December 31, 2017 was Ps. 3,466 and at December 31, 2016 was Ps. 2,415. The amount of salary advances outstanding to executive officers at March 31, 2018 was Ps. 2,363.

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Commitments

12 Months Ended

Dec. 31, 2017

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Commitments

NOTE 24. COMMITMENTS

a. PMI CIM has entered into several contracts for the sale of crude oil on the international market to foreign companies. The terms and conditions of these contracts are specific to each client, and their durations may be indefinite (evergreen contracts) or they may contain a minimum obligatory period (long-term contracts).

b. PEMEX has entered into a nitrogen supply contract for the pressure maintenance program at the Cantarell complex. During 2007, an additional contract was entered into with the purpose of supplying nitrogen to the Ku-Maloob-Zap complex and extending the original contract until 2027. At December 31, 2016 and 2015, the value of the nitrogen to be supplied during the term of the contract was approximately Ps. 7,506,619 and Ps. 8,646,726, respectively. In the event of the annulment of the contract and depending on the circumstances, PEMEX has the right or the obligation to acquire the vendor’s nitrogen plant under the terms of the contract.

Estimated future payments under this contract for upcoming fiscal years are as follows:

2018	Ps.	773,047
2019		783,197
2020		785,670
2021		786,323
2022		782,584
2023 and thereafter		3,595,798
Total	Ps.	7,506,619

c. As of December 31, 2017, PEMEX had entered into FPWCs by means of which the contractor manages and is responsible for financing performance of the work to be undertaken.

As of December 31, 2017 and 2016, the estimated value of these contracts was as follows:

Maturity	2017		2016
Up to 1 year	Ps.	5,533,174	Ps.	7,366,247
1 to 3 years		1,891,557		2,518,207
4 to 5 years		1,856,006		2,470,878
More than 5 years		3,123,173		4,157,843
Total	Ps.	12,403,910	Ps.	16,513,175

d. As of December 31, 2017 and 2016, Pemex Exploration and Production, has in operation certain integrated exploration and production contracts (“Integrated E&P Contracts”) for the development of mature fields in the Altamira, Ébano, Nejo, Pánuco and San Andrés blocks in the Northern region of Mexico and Magallanes, Santuario and Carrizo blocks in the Southern region of Mexico, respectively. Each contract has a term of up to 25 years. Payments to the contractors pursuant to the Integrated E&P Contracts will be made on a per-barrel basis, plus recovery of certain costs, provided that the payments to the contractor may not exceed PEMEX’s cash flow from the particular block subject to each contract. During 2017, PEMEX made payments pursuant to the Integrated E&P Contracts in the Northern region of Ps. 6,594,486 and in the Southern region of Ps. 727,331. During 2016, PEMEX made payments pursuant to the Integrated E&P Contracts in the Northern region of Ps. 7,026,822 and in the Southern region of Ps. 524,475. As of December 31, 2017 there is no outstanding liability due to the fact that the available cash flow has an annual maturity and has not yet matured. Additionally, these contracts are in the process of being migrated to a new EEC.

e. As of December 31, 2017 and 2016, the estimated value of the contracts that PEMEX has entered into with several contractors for the development of various infrastructure and services works was as follows:

Maturity	2017		2016
Up to 1 year	Ps.	229,738,368	Ps.	347,606,848
1 to 3 years		196,335,411		281,563,607
4 to 5 years		123,159,215		69,541,826
More than 5 years		149,672,236		119,281,849
Total	Ps.	698,905,230	Ps.	817,994,130

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Contingencies

12 Months Ended

Dec. 31, 2017

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Contingencies

NOTE 25. CONTINGENCIES

In the ordinary course of business, PEMEX is named in a number of lawsuits of various types. PEMEX evaluates the merit of each claim and assesses the likely outcome. PEMEX has not recorded provisions related to ongoing legal proceedings due to the fact that an unfavorable resolution is not expected in such proceedings, with the exception of the proceeding described in further detail in this Note.

PEMEX is involved in various civil, tax, criminal, administrative, labor and commercial lawsuits and arbitration proceedings. The results of these proceedings are uncertain as of the date of these consolidated financial statements. As of December 31, 2017 and 2016, PEMEX had accrued a reserve of Ps. 7,812,689 and Ps. 15,119,692, respectively, for these contingent liabilities. As of December 31, 2017, the current status of the principal lawsuits in which PEMEX is involved is as follows:

• On April 4, 2011, Pemex-Exploration and Production was summoned before the Séptima Sala Regional Metropolitana (“Seventh Regional Metropolitan Court”) of the Tribunal Federal de Justicia Fiscal y Administrativa (“Tax and Administrative Federal Court”) in connection with an administrative claim (No. 4957/1117071) filed by EMS Energy Services de México, S. de R.L. de C.V. and Energy Maintenance Services Group I. LLC requesting that Pemex-Exploration and Production’s termination of the public works contract be declared null and void. In a concurrent proceeding, the plaintiffs also filed an administrative claim (No. 13620/15-17-06) against Pemex Exploration and Production before the Sexta Sala Regional Metropolitana (“Sixth Regional Metropolitan Court”) of the Tax and Administrative Federal Court in Mexico City seeking damages totaling U.S. $193,713 related to the above-mentioned contract. Pemex-Exploration and Production filed a response requesting the two administrative claims be joined in a single proceeding, which was granted on May 10, 2016 by the Seventh Regional Metropolitan Court. On May 3, 2017, the proceeding was closed for a judgment to be issued. As of the date of these financial statements, a resolution from the Second Section of the Superior Court of the Tax and Administrative Federal Court is still pending.

• In June 2016, Pemex Exploration and Production was summoned before the Juzgado Octavo de Distrito en Materia Civil (“Eighth Civil District Court”) in Mexico City, in connection with a claim filed by Drake Mesa, S. de R.L. (file No. 200/2016-II), seeking approximately U.S.$120,856 related to expenses and damages, in connection with a public work agreement executed between them. On November 9, 2017, a judgment was issued finding the Eighth Civil District Court lacked jurisdiction over this case. Both parties filed appeals against this resolution. As of the date of these financial statements, a final resolution is still pending.

• On June 11, 2015, the Segunda Sala Regional del Noreste (“Second Regional Northeast Court”) notified Pemex-Refining of an administrative claim (file no. 2383/15-06-02-4) filed by Severo Granados Mendoza, Luciano Machorro Olvera and Hilario Martínez Cerda, as President, Secretary and Treasurer of the Ejido Tepehuaje, seeking Ps. 2,094,232 in damages due to a hydrocarbon spill on their land. Pemex-Refining filed a response to this claim and the plaintiffs were given time to amend their claim. The defendant filed a motion against this resolution and responded to the amended claim on February 17, 2017. The trial is in the evidentiary stage. The appointment of an independent expert related to environmental issues is still pending. A final judgment is still pending.

• On July 8, 2011, Pemex Exploration and Production was summoned in connection with an administrative claim (no. 4334/1111026) filed by Compañía Petrolera La Norma, S.A., against the Chief Executive Officer of Petróleos Mexicanos and the Chief Executive Officer of Pemex-Exploration and Production before the Segunda Sala Regional Hidalgo-México (“Hidalgo-Mexico Second Regional Court”) of the Tax Administrative Federal Court in Tlalnepantla, Estado de México. The plaintiff is seeking compensation for the cancellation of its alleged petroleum rights concessions and damages for up to Ps.1,552,730. On August 20, 2014, the proceeding was sent to the Segunda Sección de la Sala Superior (“Second Section of The Superior Court”) of the Tax and Administrative Federal Court (4334/11-11-02-6/1337/14-s2-07-04). On October 29, 2014, the proceeding was returned to the Second Regional Court to correct a procedural error. A new term to file pleas was approved. On September 7, 2017, a motion was filed questioning a signature’s authenticity. In December 2017, a documentary expert’s opinion was filed by the plaintiff and a new expert was designated by Pemex Exploration and Production. The acceptance of this designation is still pending. As of the date of these financial statements, a final resolution is still pending.

• On December 12, 2017, Pemex Exploration and Production was summoned in connection with an arbitration claim (no. 23217/JPA) filed by SUBSEA 7 de México, S. de R. L. de C.V. (“SUBSEA 7”) seeking U.S.$153,000 related to additional expenses in connection with a pipelines construction contract. A response by the defendant is still pending as of the date of these financial statements.

• On August 1, 2017, Pemex Exploration and Production was summoned in connection with an administrative claim (no. 11590/17-17-06-2) filed by Proyectos y Cimentaciones Industriales, S.A. de C.V. before the Sixth Regional Metropolitan Court seeking Ps. 800,000 and U.S.$ 12.82 and to have the settlement certificate dated March 22, 2017 related to services agreement declared null and void. On September 25, 2017 Pemex Exploration and Production filed a response to this claim. As of the date of these financial statements, a final resolution is still pending.

The results of these proceedings are uncertain until their final resolutions are issued by the appropriate authorities. PEMEX has recorded liabilities for loss contingencies when it is probable that a liability has been incurred and the amount thereof can be reasonably estimated. When a reasonable estimation could not be made, qualitative disclosure was provided in the notes to these consolidated financial statements.

PEMEX does not disclose amounts accrued for each individual claim because such disclosure could adversely affect PEMEX’s legal strategy, as well as the outcome of the related litigation.

Pursuant to an ordinary session held by the Board of Directors on August 23, 2013, Petróleos Mexicanos established policies for the granting of mutual guarantees, loans or any type of credit in favor of the Subsidiary Entities and Subsidiary Companies; in accordance with these policies, the Corporate Finance Department issues an opinion with its risk analysis, financial valuation, budget sufficiency, accounting treatment and conclusions.

Additionally, Pemex Logistics has granted the following corporate guarantees in connection with the exploration and extraction contracts entered into Pemex Exploration and Production, as required by the NHC:

• Exploration and extraction of hydrocarbons under the deep-water license modality, Trión field (Tender CNH-A1-TRION / 2016), of US $4,000,000.

• Exploration and extraction of the contract area 3 Cinturón plegado perdido (Tender CNHR01- L04 / 2015), of US $3,333,000.

• Extraction of hydrocarbons under shared production contract of the Ek-Balam fields, of U.S. $5,000,000.

• Extraction of hydrocarbons in contractual area Santuario and El Golpe 3 field, of U.S. $320,000.

• Exploration and extraction of hydrocarbons under shared production contract, contractual area 2 Tampico-Misantla, of U.S. $1,750,000.

• Exploration and extraction of hydrocarbons under shared production contract, contractual area 8 Cuencas del Sureste, of U.S. $1,250,000.

• Exploration and extraction of hydrocarbons shared production contract, assignment AE-0398-Mission of U.S. $255,000.

• Extraction of hydrocarbons under license agreement, Ogarrio field of U.S. $250,000.

• Extraction of hydrocarbons under license agreement, Cárdenas and Mora fields, of U.S. $250,000.

Certain other Subsidiary Entities have also granted guarantees and other contingencies.

PEMEX considers the probability it needs to make a disbursement of cash, for the guarantees granted and in effect as of December 31, 2017 remote.

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Business Combination

12 Months Ended

Dec. 31, 2017

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Business Combination

NOTE 26. BUSINESS COMBINATION

On January 28, 2016, PMX Fertilizantes Pacífico, S.A. de C.V., a PEMEX subsidiary company, acquired 99.99% of the outstanding shares of Fertinal, for a total purchase price of Ps. 4,322,826. This amount was paid through credit lines under a simple credit agreement. Additionally, within the same credit line, PMX Fertilizantes obtained U.S. $425,800 for the liquidation of Fertinal’s debt. These loans will mature in 16 years.

The net fair value of Fertinal’s assets and liabilities as of the date of acquisition is:

	Fair value
Cash and cash equivalents	Ps.	(6,943	)
Accounts receivable		102,121
Inventories		762,254
Properties, plant and equipment		9,811,928
Other assets		1,671,718
Total assets		12,341,078
Accounts payable	Ps.	2,331,540
Debt		9,365,152
Deferred taxes		328,578
Total liabilities		12,025,270
Total assets, net	Ps.	315,808
Transaction value	Ps.	4,322,826
Goodwill	Ps.	4,007,018

PMX FP carried out the purchase price allocation (PPA) of the Fertinal acquisition in accordance with International Financial Reporting Standard 3 “Business Combination”. It was determined that net assets acquired amounted to Ps. 315,808 and a goodwill of Ps. 4,007,018. As of December 31, 2016, a calculation of the impairment of goodwill resulted in the complete cancellation of that amount. The impairment of goodwill is recognized in the consolidated statement of comprehensive income in other income (expenses), net. See Note 22.

PEMEX intends to incorporate Fertinal into the gas-ammonia solid fertilizers value chain in order to strengthen its ability to offer a wide range of fertilizers and to cover approximately 50% of the domestic market, and is also assessing the possibility of selling the integrated business in the future.

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Subsequent Events

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Subsequent Events

NOTE 27. SUBSEQUENT EVENTS

During the period from January 1 to April 27, 2018, PEMEX participated in the following financing activities:

• On February, 12, 2018, Petróleos Mexicanos issued U.S. $4,000,000 of debt securities under its U.S. $92,000,000 Medium-Term Notes Program, Series C, in two tranches: (1) U.S. $2,500,000,000 5.35% Notes due 2028 and (2) U.S. $1,500,000,000 6.35% Bonds due 2048. All debt securities under this program are guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

• On February 12, 2018, Petróleos Mexicanos consummated an exchange offer pursuant to which it exchanged (1) U.S. $952,454, aggregate principal amount of its outstanding 5.500% Bonds due 2044 for U.S. $881,899, aggregate principal amount of its new 6.350% Bonds due 2048 and (2) U.S. $1,021,065, aggregate principal amount of its outstanding 5.6250% Bonds due 2046 for U.S. $946,764, aggregate principal amount of its 6.350% Bonds due 2048.

• On March 5, 2018, Petróleos Mexicanos consummated a tender offer pursuant to which it purchased U.S. $138,598, aggregate principal amount of its outstanding 3.125% Notes due 2019, U.S. $558,644 aggregate principal amount of its outstanding 5.500% Notes due 2019, U.S. $91,843 aggregate principal amount of its outstanding 8.000% Notes due 2019, U.S. $183,017 aggregate principal amount of its outstanding 6.000% Notes due 2020 and U.S. $817,303 aggregate principal amount of its outstanding 3.500% Notes due 2020.

Between January 1 to April 27, 2018, PMI HBV obtained U.S. $7,126,000 and repaid U.S. $6,126,000 in financing from its revolving credit lines. As of April 27, 2018, the outstanding amount under these revolving credit lines was U.S. $1,227,500.

As of April 27, 2018, the Mexican peso-U.S. dollar exchange rate was Ps. 19.0530 per U.S. dollar, which represents a 3.7% appreciation of the value of the peso in U.S. dollar terms as compared to the exchange rate as of December 31, 2017, which was Ps. 19.7867 per U.S. dollar.

As of April 27, 2018, the weighted average price of the crude oil exported by PEMEX was U.S. $60.89 per barrel. This represents a price increase of approximately 8.3% as compared to the average price as of December 31, 2017, which was U.S. $56.19 per barrel.

In March 2018, Pemex Exploration and Production was summoned before the International Centre for Dispute Resolution of the American Arbitration Association in connection with an arbitration claim (No. 01-18-0001-1499) filed by Loadmaster Universal Rigs, Inc., Loadmaster Drilling Technologies, LLC, Ulterra Drilling Technologies Mexico, S.A. de C.V. and Kennedy Fabricating, LLC seeking U.S. $139,870 in connection with the construction and acquisition of modular drilling equipment. Pemex Exploration and Production is currently analyzing the legal actions available to it in response to this claim.

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Subsidiary Guarantor Information

12 Months Ended

Dec. 31, 2017

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Subsidiary Guarantor Information

NOTE 28. SUBSIDIARY GUARANTOR INFORMATION

The following consolidating information presents: (i) condensed consolidated statements of financial position at December 31, 2017 and 2016 and condensed consolidated statements of comprehensive income and cash flows for the years ended December 31, 2017, 2016 and 2015 of Petróleos Mexicanos, the Subsidiary Guarantors and the Non-Guarantor Subsidiaries (as defined below).

These condensed consolidated statements were prepared in conformity with IFRS, with one exception: for the purposes of the presentation of the subsidiary guarantor information, the Subsidiary Entities and Subsidiary Companies have been accounted for as investments under the equity method by Petróleos Mexicanos. Earnings of subsidiaries are therefore reflected in Petróleos Mexicanos’ investment account and earnings. The principal elimination entries eliminate Petróleos Mexicanos’ investment in subsidiaries and inter-company balances and transactions. Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services (collectively, the “Subsidiary Guarantors”) and Pemex Ethylene and Pemex Fertilizers are 100%-owned subsidiaries of the Mexican Government. The guaranties by the Subsidiary Guarantors of Petróleos Mexicanos’ payment obligations under this indebtedness are full, unconditional, joint and several. Pemex Ethylene, Pemex Fertilizers, Pemex Finance, Ltd. and the Subsidiary Companies collectively comprise the non-guarantor subsidiaries (the “Non-Guarantor Subsidiaries”).

The Pemex Project Funding Master Trust (the “Master Trust”), which was a trust formed for the purpose of financing PEMEX’s projects, was dissolved effective December 20, 2011 and is no longer consolidated in the financial statements of PEMEX as of December 31, 2011 and thereafter.

The following table sets forth, as of December 31, 2017, the principal amount outstanding of the registered debt securities originally issued by the Master Trust. As noted above, Petróleos Mexicanos has assumed, as primary obligor, all of the obligations of the Master Trust under these debt securities. The obligations of Petróleos Mexicanos are guaranteed by the Subsidiary Guarantors:

Table 1: Registered Debt Securities originally issued by the Master Trust and Assumed by Petróleos Mexicanos

Security	Primary obligor	Guarantors	Principal amount outstanding (U.S. $)
5.75% Guaranteed Notes due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		834,688
6.625% Guaranteed Bonds due 2035	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,750,000
6.625% Guaranteed Bonds due 2038	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		491,175
8.625% Bonds due 2022	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		160,245
8.625% Guaranteed Bonds due 2023	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		106,507
9 1⁄4% Guaranteed Bonds due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		107,109
9.50% Guaranteed Bonds due 2027	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		219,217

The following table sets forth, as of December 31, 2017, the principal amount outstanding of the registered debt securities issued by Petróleos Mexicanos, and guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

Table 2: Registered Debt Securities originally issued by Petróleos Mexicanos

Security	Issuer	Guarantors	Principal amount outstanding (U.S. $)
8.00% Notes due 2019	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,312,015
9 1⁄4% Global Guaranteed Bonds due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		9,296
9.50% Global Guaranteed Bonds due 2027	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		102,149
3.500% Notes due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		355,356
Floating Rate Notes due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		498,570
6.000% Notes due 2020	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		995,364
5.50% Notes due 2021	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,962,047
3.500% Notes due 2023	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,099,730
4.875% Notes due 2024	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,499,136
6.625% Notes due 2035	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		999,000
6.500% Bonds due 2041	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		3,000,000
4.875% Bonds 2022	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,097,055
3.125% Notes due 2019	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		325,778
3.500% Notes due 2020	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,465,367
5.50% Bonds due 2044	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,657,962
6.375% Bonds due en 2045	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,999,980
5.625% Bonds due 2046	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,996,226
4.500% Notes due 2026	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,489,718
4.250% Notes due 2025	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		998,435
5.500% Notes due 2019	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		740,851
6.375% Notes due 2021	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,247,668
6.875% Notes due 2026	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,970,334
4.625% Notes due 2023	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,055,498
6.750% Notes due 2047	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		3,671,628

Petróleos Mexicanos is the only PEMEX entity that had debt securities registered with the SEC outstanding as of December 31, 2017 and as of the date of these consolidated financial statements, and all guaranteed debt is issued by Petróleos Mexicanos. The guaranties of the Subsidiary Guarantors are full and unconditional and joint and several. PEMEX’s management has not presented separate financial statements for the Subsidiary Guarantors, because it has determined that such information is not material to investors.

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF FINANCIAL POSITION

As of December 31, 2017

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries		Eliminations			PEMEX consolidated
Assets
Current assets
Cash and cash equivalents	Ps.	46,959,103		Ps.	18,815,345		Ps.	32,077,306	Ps.	—		Ps.	97,851,754
Accounts receivable and other, net, and derivative financial instruments		83,119,394			38,105,354			79,533,940		—			200,758,688
Accounts receivable—inter-company		311,148,593			1,380,100,592			86,354,837		(1,777,604,022	)		—
Inventories		509,375			32,357,125			30,992,430		—			63,858,930
Available-for-sale financial assets		—			—			1,056,918		—			1,056,918
Total current assets		441,736,465			1,469,378,416			230,015,431		(1,777,604,022	)		363,526,290
Long-term receivables—intercompany		1,823,276,758			285			3,597,880		(1,826,874,923	)		—
Investments in joint ventures and associates		(465,832,399	)		82,668			16,611,681		465,845,414			16,707,364
Wells, pipelines, properties, plant and equipment-net		12,444,376			1,370,974,060			53,090,890		—			1,436,509,326
Long-term notes receivables		147,286,367			1,206,542			—		—			148,492,909
Deferred taxes		59,691,528			84,443,897			2,057,060		—			146,192,485
Intangible assets		—			9,088,563			—		—			9,088,563
Other assets		2,209,579			4,846,078			4,429,520		—			11,485,177
Total assets	Ps.	2,020,812,674		Ps.	2,940,020,509		Ps.	309,802,462	Ps.	(3,138,633,531	)	Ps.	2,132,002,114
Liabilities
Current liabilities
Current portion of long-term debt	Ps.	137,947,110		Ps.	5,386,564		Ps.	13,875,793	Ps.	—		Ps.	157,209,467
Accounts payable—inter-company		1,240,490,891			434,556,688			93,140,905		(1,768,188,484	)		—
Other current liabilities		23,435,614			157,589,107			50,892,997		—			231,917,718
Total current liabilities		1,401,873,615			597,532,359			157,909,695		(1,768,188,484	)		389,127,185
Long-term debt		1,824,829,579			40,262,391			15,573,634		—			1,880,665,604
Long-term payables—inter-company		—			1,830,150,615			6,139,845		(1,836,290,460	)		—
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		297,028,436			1,057,191,286			10,341,988		—			1,364,561,710
Total liabilities		3,523,731,630			3,525,136,651			189,965,162		(3,604,478,944	)		3,634,354,499
Equity (deficit), net		(1,502,918,956	)		(585,116,142	)		119,837,300		465,845,413			(1,502,352,385	)
Total liabilities and equity	Ps.	2,020,812,674		Ps.	2,940,020,509		Ps.	309,802,462	Ps.	(3,138,633,531	)	Ps.	2,132,002,114

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF FINANCIAL POSITION

As of December 31, 2016

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries		Eliminations			PEMEX consolidated
Assets
Current assets
Cash and cash equivalents	Ps.	92,503,607		Ps.	9,732,503		Ps.	61,296,403	Ps.	—		Ps.	163,532,513
Accounts receivable and other, net, and derivative financial instruments		6,604,595			75,760,079			55,713,323		—			138,077,997
Accounts receivable—inter-company		440,645,367			1,684,782,235			70,268,246		(2,195,695,848	)		—
Inventories		446,954			29,270,943			16,174,163		—			45,892,060
Available-for-sale financial assets		—			—			2,852,679		—			2,852,679
Held-for-sale non-financial assets		—			7,460,674			—		—			7,460,674
Total current assets		540,200,523			1,807,006,434			206,304,814		(2,195,695,848	)		357,815,923
Available-for-sale financial assets		—			—			6,027,540		—			6,027,540
Long-term receivables—intercompany		1,740,519,399			289			6,384,944		(1,746,904,632	)		—
Investments in joint ventures and associates		(250,108,630	)		396,681			20,327,813		250,121,645			20,737,509
Wells, pipelines, properties, plant and equipment-net		12,596,722			1,595,655,580			59,489,946		—			1,667,742,248
Long-term notes receivables		140,579,974			8,027,628			—		—			148,607,602
Deferred taxes		59,162,878			40,341,615			820,196		—			100,324,689
Restricted cash		—			9,624,804			853,822		—			10,478,626
Intangible assets		—			8,639,242			—		—			8,639,242
Other assets		1,824,104			2,707,788			4,980,753		—			9,512,645
Total assets	Ps.	2,244,774,970		Ps.	3,472,400,061		Ps.	305,189,828	Ps.	(3,692,478,835	)	Ps.	2,329,886,024
Liabilities
Current liabilities
Current portion of long-term debt		157,937,631			7,381,095			10,847,462		—			176,166,188
Accounts payable—inter-company		1,265,244,986			854,106,939			68,510,835		(2,187,862,760	)		—
Other current liabilities		34,913,773			169,182,239			45,927,686		—			250,023,698
Total current liabilities		1,458,096,390			1,030,670,273			125,285,983		(2,187,862,760	)		426,189,886
Long-term debt		1,737,332,174			46,090,919			23,581,449		—			1,807,004,542
Long-term payables—inter-company		—			1,746,433,870			8,303,850		(1,754,737,720	)		—
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		282,902,667			1,035,019,339			11,777,737		—			1,329,699,743
Total liabilities		3,478,331,231			3,858,214,401			168,949,019		(3,942,600,480	)		3,562,894,171
Equity (deficit), net		(1,233,556,261	)		(385,814,340	)		136,240,809		250,121,645			(1,233,008,147	)
Total liabilities and equity	Ps.	2,244,774,970		Ps.	3,472,400,061		Ps.	305,189,828	Ps.	(3,692,478,835	)	Ps.	2,329,886,024

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF COMPREHENSIVE INCOME

For the year ended December 31, 2017

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Net sales	Ps.	—		Ps.	1,713,914,703		Ps.	1,096,752,930		Ps.	(1,424,768,483	)	Ps.	1,385,899,150
Services income		50,399,983			140,934,022			2,646,144			(182,849,580	)		11,130,569
Total sales revenues		50,399,983			1,854,848,725			1,099,399,074			(1,607,618,063	)		1,397,029,719
Impairment of wells, pipelines, properties, plant and equipment		—			145,302,407			6,142,153			—			151,444,560
Cost of sales		2,007,814			1,447,640,131			1,083,297,610			(1,528,740,675	)		1,004,204,880
Gross income		48,392,169			261,906,187			9,959,311			(78,877,388	)		241,380,279
Other revenues (expenses), net		(341,521	)		(12,443,660	)		(4,664,096	)		22,623,353			5,174,076
General expenses:
Transportation, distribution and sale expenses		—			26,136,674			1,297,558			(5,544,562	)		21,889,670
Administrative expenses		59,141,391			105,920,390			5,883,200			(51,005,527	)		119,939,454
Total general expenses		59,141,391			132,057,064			7,180,758			(56,550,089	)		141,829,124
Operating income		(11,090,743	)		117,405,463			(1,885,543	)		296,054			104,725,231
Financing income		143,676,367			134,401,598			3,185,195			(265,097,307	)		16,165,853
Financing cost		(236,929,035	)		(141,900,236	)		(3,616,530	)		264,801,253			(117,644,548	)
Derivative financial instruments income (cost), net		27,670,991			(1,608,039	)		(724,628	)		—			25,338,324
Foreign exchange income , net		6,837,171			15,807,988			538,963			—			23,184,122
Profit (loss) sharing in joint ventures and associates		(211,567,169	)		409,955			(49,515	)		211,567,169			360,440
Income (loss) before taxes, duties and other		(281,402,418	)		124,516,729			(2,552,058	)		211,567,169			52,129,422
Total taxes, duties and other		(557,520	)		331,001,261			2,536,300			—			332,980,041
Net (loss) income for the year		(280,844,898	)		(206,484,532	)		(5,088,358	)		211,567,169			(280,850,619	)
Total other comprehensive result		4,728,640			6,841,586			(63,845	)		—			11,506,381
Total comprehensive result for the year	Ps.	(276,116,258	)	Ps.	(199,642,946	)	Ps.	(5,152,203	)	Ps.	211,567,169		Ps.	(269,344,238	)

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF COMPREHENSIVE INCOME

For the year ended December 31, 2016

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Net sales	Ps.	—		Ps.	1,361,538,624		Ps.	828,143,332		Ps.	(1,124,563,366	)	Ps.	1,065,118,590
Services income		46,330,245			98,959,131			1,970,055			(138,284,789	)		8,974,642
Total sales revenues		46,330,245			1,460,497,755			830,113,387			(1,262,848,155	)		1,074,093,232
(Reversal) impairment of wells, pipelines, properties, plant and equipment		—			(330,037,834	)		(1,276,509	)		—			(331,314,343	)
Cost of sales		1,236,921			1,244,388,072			809,156,778			(1,188,959,550	)		865,822,221
Gross income		45,093,324			546,147,517			22,233,118			(73,888,605	)		539,585,354
Other revenues (expenses), net		(312,611	)		20,713,184			2,915,837			(666,804	)		22,649,606
General expenses:
Transportation, distribution and sale expenses		—			50,948,771			945,489			(26,663,020	)		25,231,240
Administrative expenses		57,437,455			96,884,031			7,050,271			(48,718,224	)		112,653,533
Total general expenses		57,437,455			147,832,802			7,995,760			(75,381,244	)		137,884,773
Operating income		(12,656,742	)		419,027,899			17,153,195			825,835			424,350,187
Financing income		123,266,281			67,542,768			3,526,378			(180,586,172	)		13,749,255
Financing cost		(160,824,632	)		(114,271,762	)		(3,602,868	)		179,854,798			(98,844,464	)
Derivative financial instruments (cost) income, net		(12,052,200	)		3,172			(1,951,959	)		—			(14,000,987	)
Foreign exchange loss, net		(20,531,005	)		(232,714,446	)		(767,292	)		—			(254,012,743	)
Profit (loss) sharing in joint ventures and associates		(117,347,803	)		628,357			1,507,488			117,347,803			2,135,845
Income (loss) before taxes, duties and other		(200,146,101	)		140,215,988			15,864,942			117,442,264			73,377,093
Total taxes, duties and other		(8,834,626	)		266,155,181			7,200,880			—			264,521,435
Net (loss) income for the year		(191,311,475	)		(125,939,193	)		8,664,062			117,442,264			(191,144,342	)
Total other comprehensive result		10,126,560			96,032,433			21,713,488			—			127,872,481
Total comprehensive result for the year	Ps.	(181,184,915	)	Ps.	(29,906,760	)	Ps.	30,377,550		Ps.	117,442,264		Ps.	(63,271,861	)

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF COMPREHENSIVE INCOME

For the year ended December 31, 2015

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Net sales	Ps.	15,556		Ps.	1,523,767,800		Ps.	803,623,324		Ps.	(1,173,956,323	)	Ps.	1,153,450,357
Services income		16,897,139			16,815,589			2,585,617			(27,988,310	)		8,310,035
Total sales revenues		16,912,695			1,540,583,389			806,208,941			(1,201,944,633	)		1,161,760,392
Impairment of wells, pipelines, properties, plant and equipment		—			476,276,159			1,668,531			—			477,944,690
Benefit from change in pension plan					(83,657,496	)		(8,519,593	)		—			(92,177,089	)
Cost of sales		2,695,423			1,280,404,059			791,147,745			(1,182,282,621	)		891,964,606
Gross income		14,217,272			(132,439,333	)		21,912,258			(19,662,012	)		(115,971,815	)
Other (expenses) revenues, net		(19,805	)		(6,073,003	)		3,326,421			1,890,900			(875,487	)
General expenses:
Transportation, distribution and sale expenses		—			32,870,908			2,921,430			(6,863,699	)		28,928,639
Administrative expenses		59,923,878			52,832,029			10,638,127			(10,921,939	)		112,472,095
Benefit from change in pension plan		(46,031,780	)		(50,394,477	)		(7,434,698	)		—			(103,860,955	)
Total general expenses		13,892,098			35,308,460			6,124,859			(17,785,638	)		37,539,779
Operating income		305,369			(173,820,796	)		19,113,820			14,526			(154,387,081	)
Financing income		108,543,665			28,639,034			3,478,434			(125,670,274	)		14,990,859
Financing cost		(85,544,060	)		(104,453,148	)		(3,306,776	)		125,530,391			(67,773,593	)
Derivative financial instruments (cost) income, net		(22,803,663	)		6,463			1,347,323			—			(21,449,877	)
Foreign exchange loss, net		(14,829,436	)		(139,623,910	)		(312,228	)		—			(154,765,574	)
(Loss) profit sharing in joint ventures and associates		(749,963,960	)		198,786			2,119,329			749,963,960			2,318,115
(Loss) income before taxes, duties and other		(764,292,085	)		(389,053,571	)		22,439,902			749,838,603			(381,067,151	)
Total taxes, duties and other		(51,982,560	)		376,649,369			6,833,438			—			331,500,247
Net (loss) income for the year		(712,309,525	)		(765,702,940	)		15,606,464			749,838,603			(712,567,398	)
Total other comprehensive result		10,980,787			56,585,790			21,045,777			—			88,612,354
Total comprehensive result for the year	Ps.	(701,328,738	)	Ps.	(709,117,150	)	Ps.	36,652,241		Ps.	749,838,603		Ps.	(623,955,044)

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF CASH FLOWS

For the year ended December 31, 2017

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Operating activities:
Net (loss) income for the year	Ps.	(280,844,898	)	Ps.	(206,484,532	)	Ps.	(5,082,639	)	Ps.	211,561,450		Ps.	(280,850,619	)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization		1,155,881			152,607,943			2,940,689			—			156,704,513
Impairment of wells, pipelines, properties, plant and equipment		—			145,302,407			6,142,153			—			151,444,560
Unsuccessful wells		—			6,164,624			—			—			6,164,624
Exploration costs		—			(1,447,761	)		—			—			(1,447,761	)
Disposal of wells, pipelines, properties, plant and equipment		433,391			14,687,229			1,943,051			—			17,063,671
Gain on sale of share in joint ventures and associates		—			(3,139,103	)		—			—			(3,139,103	)
Disposal of held—for—sale current non—financial assets		—			2,808,360			—			—			2,808,360
Dividends		—			—			(180,675	)		—			(180,675	)
Effects of net present value of reserve for well abandonment		—			7,774,000			—			—			7,774,000
Profit (loss) sharing in investments		211,567,169			(409,955	)		49,515			(211,567,169	)		(360,440	)
Decrease on available—for-sale financial assets		—			—			1,360,205			—			1,360,205
Net loss on available-for-sale financial assets		—			—			3,523,748			—			3,523,748
Unrealized foreign exchange loss (gain)		(13,526,153	)		(1,585,910	)		(1,573,376	)		—			(16,685,439	)
Interest expense		100,545,114			15,736,420			1,363,014			—			117,644,548
Funds (used in) from operating activities:
Accounts receivable, accounts payable and derivative financial instruments		(88,496,967	)		(14,214,566	)		(20,789,692	)		—			(123,501,225	)
Inventories		(62,421	)		(3,086,181	)		(14,818,268	)		—			(17,966,870	)
Other assets		(7,091,867	)		(483,389	)		551,233			—			(7,024,023	)
Employee benefits		18,829,768			31,489,785			(254,157	)		—			50,065,396
Inter-company charges and deductions		7,284,124			(114,968,213	)		514,270			107,169,819			—
Cash flows (used in) from operating activities		(50,206,859	)		30,751,158			(24,310,929	)		107,164,100			63,397,470
Investing activities:
Acquisition of wells, pipelines, properties, plant and equipment		(1,436,926	)		(87,274,561	)		(3,147,978	)		—			(91,859,465	)
Resources from sale available-for-sale financial assets		—			—			8,026,836			—			8,026,836
Resources from sale of shares in associates		—			3,863,072			(721,362	)		—			3,141,710
(Increase) decrease due to Inter-company investing		25,611,359			—			—			(25,611,359	)		—
Cash flows used in investing activities		24,174,433			(83,411,489	)		4,157,496			(25,611,359	)		(80,690,919	)
Financing activities:
Loans obtained from financial institutions		401,947,349			—			302,768,119			—			704,715,468
Debt payments, principal only		(327,703,729	)		(7,981,937	)		(306,374,153	)		—			(642,059,819	)
Interest paid		(93,755,698	)		(13,991,633	)		(1,163,086	)		—			(108,910,417	)
Inter-company increase (decrease) financing		—			83,716,743			(2,164,002	)		(81,552,741	)		—
Cash flows provided by financing activities:		(19,512,078	)		61,743,173			(6,933,122	)		(81,552,741	)		(46,254,768	)
Net (decrease) increase in cash and cash equivalents		(45,544,504	)		9,082,842			(27,086,555	)		—			(63,548,217	)
Effects of change in cash value		—			—			(2,132,542	)		—			(2,132,542	)
Cash and cash equivalents at the beginning of the year		92,503,607			9,732,503			61,296,403			—			163,532,513
Cash and cash equivalents at the end of the year	Ps.	46,959,103		Ps.	18,815,345		Ps.	32,077,306		Ps.	—		Ps.	97,851,754

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF CASH FLOWS

For the year ended December 31, 2016

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Operating activities:
Net (loss) income for the year	Ps.	(191,311,476	)	Ps.	(139,410,398	)	Ps.	22,160,755		Ps.	117,416,777		Ps.	(191,144,342	)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization		1,066,033			146,545,307			2,828,151			—			150,439,491
(Reversal) impairment of wells, pipelines, properties, plant and equipment		—			(330,037,834	)		(1,276,509	)		—			(331,314,343	)
Unsuccessful wells		—			29,106,084			—			—			29,106,084
Exploration costs		—			(2,022,826	)		—			—			(2,022,826	)
Disposal of wells, pipelines, properties, plant and equipment		320,599			2,658,625			792,063			—			3,771,287
Loss in sale of fixed assets		—			27,882,480			—			—			27,882,480
Gain on sale of share in joint ventures and associates		—			(15,211,039	)		—			—			(15,211,039	)
Profit (loss) sharing in joint ventures and associates		117,249,643			(628,356	)		(1,507,489	)		(117,249,643	)		(2,135,845	)
Impairment of goodwill		—			—			4,007,018			—			4,007,018
Dividends		—			—			(293,397	)		—			(293,397	)
Effects of net present value of reserve for well abandonment		—			11,968,966			—			—			11,968,966
Unrealized foreign exchange loss (gain)		231,191,646			6,754,046			5,237,072			—			243,182,764
Interest expense		91,044,541			5,687,502			2,112,421			—			98,844,464
Funds (used in) from operating activities:
Accounts receivable, accounts payable and derivative financial instruments		23,636,331			(158,449,370	)		45,028,534			—			(89,784,505	)
Inventories		83,317			3,508,494			(4,950,690	)		—			(1,358,879	)
Other assets		(2,405,412	)		(22,600,504	)		(122,614	)		—			(25,128,530	)
Employee benefits		2,591,000			136,354,337			(91,652,268	)		—			47,293,069
Inter-company charges and deductions		(393,835,932	)		(83,049,125	)		48,435,633			428,449,424			—
Cash flows (used in) from operating activities		(120,369,710	)		(380,943,611	)		30,798,680			428,616,558			(41,898,083	)
Investing activities:
Acquisition of wells, pipelines, properties, plant and equipment		(2,172,586	)		(147,786,686	)		(1,449,208	)		—			(151,408,480	)
Resources from sale on share in associates		—			23,050,344			(365,608	)		—			22,684,736
Proceeds from the sale of fixed assets		—			560,665			—			—			560,665
Business acquisition		—			—			(4,329,769	)		—			(4,329,769	)
(Increase) decrease due to Inter-company investing		(39,612,699	)		—			—			39,612,699			—
Cash flows used in investing activities		(41,785,285	)		(124,175,677	)		(6,144,585	)		39,612,699			(132,492,848	)
Financing activities:
Increase in equity due to Certificates of Contributions “A”		73,500,000			—			—			—			73,500,000
Loans obtained from financial institutions		571,944,209			34,483,348			235,564,210			—			841,991,767
Debt payments, principal only		(372,809,166	)		(6,414,441	)		(235,763,722	)		—			(614,987,329	)
Interest paid		(82,008,347	)		(4,706,946	)		(2,038,848	)		—			(88,754,141	)
Inter-company increase (decrease) financing		—			464,488,030			3,741227			(468,229,257	)		—
Cash flows provided by financing activities:		190,626,696			487,849,991			1,502,867			(468,229,257	)		211,750,297
Net (decrease) increase in cash and cash equivalents		28,471,701			(17,269,297	)		26,156,962			—			37,359,366
Effects of change in cash value		5,570,892			20,371,126			(9,137,751	)		—			16,804,267
Cash and cash equivalents at the beginning of the year		58,461,014			6,630,674			44,277,192			—			109,368,880
Cash and cash equivalents at the end of the year	Ps.	92,503,607		Ps.	9,732,503		Ps.	61,296,403		Ps.	—		Ps.	163,532,513

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF CASH FLOWS

For the year ended December 31, 2015

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Operating activities:
Net (loss) income for the year	Ps.	(712,177,124	)	Ps.	(765,702,826	)	Ps.	15,738,868		Ps.	749,573,684		Ps.	(712,567,398	)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization		789,657			164,221,429			2,940,164			—			167,951,250
Impairment of wells, pipelines, properties, plant and equipment		—			476,276,159			1,668,531			—			477,944,690
Unsuccessful wells		—			23,213,519			—			—			23,213,519
Exploration costs		—			(5,698,511	)		—			—			(5,698,511	)
Disposal of wells, pipelines, properties, plant and equipment		180,992			21,945,266			2,512,279			—			24,638,537
Profit (loss) sharing in joint ventures and associates		749,963,958			(198,786	)		(2,119,329	)		(749,963,958	)		(2,318,115	)
Gain on sale of share in joint ventures and associates		—			(337,675	)		(342,955	)		—			(680,630	)
Dividends		—			—			(359,941	)		—			(359,941	)
Effects of net present value of reserve for well abandonment		—			(608,160	)		—			—			(608,160	)
Unrealized foreign exchange loss (gain)		145,971,158			2,996,219			3,708,879			—			152,676,256
Interest expense		63,460,443			3,414,430			898,720			—			67,773,593
Funds provided by (used in) operating activities:
Accounts receivable, accounts payable and derivative financial instruments		(58,554,144	)		119,761,648			(27,777,939	)		—			33,429,565
Inventories		108,568			4,547,843			1,511,317			—			6,167,728
Other assets		(149,819	)		(16,578,827	)		126,281			—			(16,602,365	)
Employee benefits		(10,037,444	)		(94,183,192	)		(11,801,596	)		—			(116,022,232	)
Inter-company charges and deductions		(310,384,820	)		30,044,041			31,975,215			248,365,564			—
Cash flows provided by operating activities		(130,828,575	)		(36,887,423	)		18,678,494			247,975,290			98,937,786
Investing activities:
Acquisition of wells, pipelines, properties, plant and equipment		(1,496,277	)		(239,315,507	)		(12,702,217	)		—			(253,514,001	)
Investments in associates		—			—			(36,214	)		—			(36,214	)
Resources from the sales on share in associates		—			(130,323	)		4,547,461			—			4,417,138
(Increase) decrease due to Inter-company investing		(39,108,879	)		—			—			39,108,879			—
Cash flows used in investing activities		(40,605,156	)		(239,445,830	)		(8,190,970	)		39,108,879			(249,133,077	)
Financing activities:
Increase in equity due to Certificates of Contributions “A”		10,000,000			(1,915,922	)		1,844,394			71,528			10,000,000
Loans obtained from financial institutions		345,383,990			—			33,587,088			—			378,971,078
Debt payments, principal only		(147,927,857	)		(8,081,177	)		(37,609,464	)		—			(193,618,498	)
Interest paid		(58,123,368	)		(3,443,923	)		(1,169,859	)		—			(62,737,150	)
Inter-company increase (decrease) financing		(3,626,448	)		289,859,173			922,972			(287,155,697	)		—
Cash flows provided by financing activities:		145,706,317			276,418,151			(2,424,869	)		(287,084,169	)		132,615,430
Net (decrease) increase in cash and cash equivalents		(25,727,414	)		84,898			8,062,655			—			(17,579,861	)
Effects of change in cash value		11,185,788			1,138,356			(3,363,931	)		—			8,960,213
Cash and cash equivalents at the beginning of the year		73,002,640			5,407,420			39,578,468			—			117,988,528
Cash and cash equivalents at the end of the year	Ps.	58,461,014		Ps.	6,630,674		Ps.	44,277,192		Ps.	—		Ps.	109,368,880

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Supplementary Information on Oil and Gas Exploration And Production Activities (Unaudited)

12 Months Ended

Dec. 31, 2017

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Supplementary Information on Oil and Gas Exploration And Production Activities (Unaudited)

NOTE 29. SUPPLEMENTARY INFORMATION ON OIL AND GAS EXPLORATION AND PRODUCTION ACTIVITIES (UNAUDITED)

Under the Mexican Constitution, all crude oil and other hydrocarbon reserves located in the subsoil of Mexico are owned by the Mexican nation and not by PEMEX. In August 2014, through the Round Zero process, the Mexican Government granted PEMEX the right to extract, but not own, certain petroleum and other hydrocarbon reserves in Mexico through assignment deeds.

This note provides supplementary information on the oil and gas exploration, development and production activities of Pemex Exploration and Production in compliance with the U.S. Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 932 10-5 “Extractive Activities—Oil and Gas” (“ASC Topic 932”) and Accounting Standards Update 2010-03 (see Note 3(i)).

As of the date of these consolidated financial statements, all exploration and production activities of Pemex Exploration and Production are conducted in Mexico. The supplemental data presented herein reflect information for all of Pemex Exploration and Production’s oil and gas producing activities.

a. Capitalized costs for oil and gas producing activities (unaudited):

	As of December 31,
	2017			2016			2015
Proved reserves	Ps.	2,363,336,481		Ps.	2,476,535,503		Ps.	2,102,971,025
Construction in progress		35,381,089			60,720,261			88,706,330
Accumulated depreciation and amortization		(1,444,962,317	)		(1,355,402,150	)		(1,224,690,867	)
Net capitalized costs	Ps.	953,755,253		Ps.	1,181,853,614		Ps.	966,986,487

b. Costs incurred for oil and gas property exploration and development activities (unaudited):

	As of December 31,
	2017		2016
Exploration	Ps.	32,480,801	Ps.	41,661,666
Development		53,460,364		113,895,246
Total costs incurred	Ps.	85,941,165	Ps.	155,556,912

There are no property acquisition costs because PEMEX exploits oil reserves owned by the Mexican nation.

Exploration costs include costs for geological and geophysical studies of fields amounting to Ps. 8,828,809 and Ps. 6,804,341, for 2017 and 2016, respectively, that, in accordance with the successful efforts method of accounting, are accounted for as geological and geophysical exploration expenses.

Development costs include costs incurred in obtaining access to proved reserves and providing facilities for extracting, treating, gathering and storing oil and gas.

c. Results of operations for oil and gas producing activities (unaudited):

	2017			2016			2015
Revenues from sale of oil and gas	Ps.	762,637,362		Ps.	616,380,608		Ps.	690,591,455
Hydrocarbon duties		375,156,405			304,299,019			376,682,705
Production costs (excluding taxes)		248,957,950			171,194,337			177,774,082
Other costs and expenses		(3,954,222	)		61,359,271			20,360,540
Exploration expenses		14,993,433			39,693,273			31,244,564
Depreciation, depletion, amortization and accretion		240,672,906			(150,891,739	)		527,014,056
		875,826,472			425,654,161			1,133,075,947
Results of operations for oil and gas producing activities	Ps.	(113,189,111	)	Ps.	190,726,447		Ps.	(442,484,491	)

Note: Numbers may not total due to rounding.

d. Sales prices (unaudited)

The following table summarizes average sales prices in U.S. dollars for each of the years ended December 31 (excluding production taxes):

	2017		2016		2015
Weighted average sales price per barrel of oil equivalent (boe)(1)	US$	38.63	US$	29.18	US$	37.17
Crude oil, per barrel		48.71		36.55		48.22
Natural gas, per thousand cubic feet		4.32		3.01		3.78

(1) To convert dry gas to barrels of oil equivalent, a factor of 5.201 thousand cubic feet of dry gas per barrel of oil equivalent is used.

e. Crude oil and natural gas reserves (unaudited)

Under the Mexican Constitution, all oil and other hydrocarbon reserves located in the subsoil of Mexico are owned by the Mexican nation and not by PEMEX. Under the Petróleos Mexicanos Law, Pemex Exploration and Production has the right to extract, but not own, these reserves, and to sell the resulting production. The exploration and development activities of Petróleos Mexicanos and the Subsidiary Entities are limited to reserves located in Mexico.

Proved oil and natural gas reserves are those estimated quantities of crude oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be economically producible from a given date forward, from known reservoirs and under existing economic conditions, operating methods and government regulations.

Proved reserves estimates as of December 31, 2017 were prepared by the exploration and production segment and were reviewed by the Independent Engineering Firms (as defined below), which audit its estimates of its hydrocarbon reserves. In addition, pursuant to the Reglamento de la Ley de Hidrocarburos (Regulations to the Hydrocarbons Law), on March 23, 2018 the NHC reviewed and approved the proved reserves estimates as of December 31, 2017.

Pemex Exploration and Production estimates reserves based on generally accepted petroleum engineering and evaluation methods and procedures, which are based primarily on applicable SEC regulations and, as necessary, the SPE’s publication entitled Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information, dated February 19, 2007 and other SPE publications, including the SPE’s publication entitled Petroleum Resources Management System, as well as other technical sources, including Estimation and Classification of Reserves of Crude Oil, Natural Gas, and Condensate, by Chapman Cronquist, and Determination of Oil and Gas Reserves, Petroleum Society Monograph Number 1, published by the Canadian Institute of Mining and Metallurgy & Petroleum. The choice of method or combination of methods employed in the analysis of each reservoir is determined by:

• Experience in the area

• Stage of development

• Quality and completeness of basic data

• Production and pressure histories

Reserves data set forth herein represents only estimates. Reserves valuation is a subjective process of estimating underground accumulations of crude oil and natural gas that cannot be measured in an exact manner. The accuracy of any reserves estimate depends on the quality of available data, engineering and geological interpretation and professional judgment. As a result, estimates of different engineers may vary. In addition, the results of drilling, testing and producing subsequent to the date of an estimate may lead to the revision of an estimate.

During 2017, PEMEX did not record any material increase in PEMEX’s hydrocarbons reserves as a result of the use of new technologies.

In order to ensure the reliability of PEMEX’s reserves estimation efforts, it has undertaken the internal certification of its estimates of reserves since 1996. PEMEX has established certain internal controls in connection with the preparation of its proved reserves estimates. Initially, teams of geoscientists from Pemex Exploration and Production’s exploration and exploitation business units (with each of these units covering several projects) prepare the reserves estimates, using distinct estimation processes for valuations relating to new discoveries and developed fields, respectively. Subsequently, the regional reserves offices collect these reserves estimates from the units and request that the Gerencia de Recursos y Certificación de Reservas (Office of Resources and Reserves Certification), the central hydrocarbon reserves management body of Pemex Exploration and Production, review and certify such valuations and the booking of the related reserves. This internal certification process is undertaken in accordance with internal guidelines for estimating and classifying hydrocarbon reserves, which are based on the SEC’s rules and definitions. The Office of Resources and Reserves Certification, which additionally oversees and conducts an internal audit of the above process, consists entirely of professionals with geological, geophysical, petrophysical and reservoir engineering backgrounds. The engineers who participate in PEMEX’s reserves estimation process are experienced in: reservoir numerical simulation; well drilling and completion; pressure, volume and temperature (PVT) analysis; analytical tools used in forecasting the performance of the various elements comprising the production system; and design strategies in petroleum field development. Furthermore, all of PEMEX’s personnel have been certified by the Secretaría de Educación Pública (Ministry of Public Education), most have earned master’s degrees in areas of study such as petroleum engineering, geology and geophysical engineering and they possess an average of over fifteen years of professional experience.

In addition to this internal review process, Pemex Exploration and Production’s final reserves estimates are audited by independent engineering firms. Three independent engineering firms audited Pemex Exploration and Production’s estimates of proved reserves as of December 31, 2017: Netherland Sewell International, S. de R. L. de C. V. (“Netherland Sewell”); DeGolyer and MacNaughton (“DeGolyer”); and Ryder Scott Company, L.P. (“Ryder Scott,”) and, together with Netherland Sewell and DeGolyer and MacNaughton, the “Independent Engineering Firms”. The reserves estimates reviewed by the Independent Engineering Firms totaled 97.0% of PEMEX’s estimated proved reserves. The remaining 3.0% of PEMEX’s estimated proved reserves consisted of reserves located in certain areas in which third parties provide drilling services to Pemex Exploration and Production. Under such agreements, the corresponding third party is responsible of assessing the volume of reserves.

Netherland Sewell audited the reserves in the Poza Rica-Altamira, Aceite Terciario del Golfo and Litoral de Tabasco assets. DeGolyer in Burgos and Veracruz Assets and Ryder Scott audited the reserves in the Bellota-Jujo, Cinco Presidentes, Macuspana-Muspac, Samaria-Luna, Abkatún-Pol-Chuc, Cantarell and Ku-Maloob-Zaap Assets. The audits conducted by the Independent Engineering Firms consisted primarily of: (1) analysis of historical static and dynamic reservoir data provided by Pemex-Exploration and Production; (2) construction or updating of the Independent Engineering Firms’ own static and dynamic reservoir characterization models of some of the fields; (3) economic analysis of the fields; and (4) review of Pemex Exploration and Production’s production forecasts and reserves estimates.

Since reserves estimates are, by definition, only estimates, they cannot be reviewed for the purpose of verifying exactness. Instead, the Independent Engineering Firms conducted a detailed review of Pemex Exploration and Production’s reserves estimates so that they could express an opinion as to whether, in the aggregate, the reserves estimates that Pemex Exploration and Production furnished were reasonable and had been estimated and presented in conformity with generally accepted petroleum engineering and evaluation methods and procedures.

All questions, including any suggested modifications to proved reserves estimates, that arose during the Independent Engineering Firms’ review process were resolved by Pemex Exploration and Production to the satisfaction of the Independent Engineering Firms. The Independent Engineering Firms have concluded that PEMEX’s estimated total proved oil and natural gas reserve volumes set forth in this report are, in the aggregate, reasonable and have been prepared in accordance with Rule 4-10(a) are consistent with international reserves reporting practice and are in accordance with the revised oil and gas reserves disclosure provisions of ASC Topic 932.

PEMEX’s total proved developed and undeveloped reserves of crude oil, condensates and liquefiable hydrocarbons recoverable from field processing plants decreased by 11.0% in 2017, from 7,219 million barrels at December 31, 2016 to 6,427 million barrels at December 31, 2017. PEMEX’s proved developed reserves of crude oil, condensates and liquefiable hydrocarbons recoverable from processing plants decreased by 14.7% in 2017, from 4,866 million barrels at December 31, 2016 to 4,166 million barrels at December 31, 2017. These decreases were principally due to oil production in 2017, a decrease in field development activities and field behavior and the transfer to third parties, who were awarded with contracts in the bidding rounds, of certain fields that had been temporarily assigned to PEMEX and associations and alliances such as Santuario and El Golpe fields, of which PEMEX is assigned a 64% of their proved reserves . The amount of crude oil, condensate and liquefiable hydrocarbon reserves added in 2017 was insufficient to offset the level of production in 2017, which amounted to 805.5 million barrels of crude oil, condensates and liquefiable hydrocarbons.

PEMEX’s proved developed and undeveloped dry gas reserves decreased by 5.6% in 2017, from 6,984 billion cubic feet at December 31, 2016 to 6,593 billion cubic feet at December 31, 2017. PEMEX’s proved developed dry gas reserves decreased by 10.8% in 2017, from 4,513 billion cubic feet at December 31, 2016 to 4,026 billion cubic feet at December 31, 2017. These decreases were principally due to oil production in 2017, a decrease in field development activities and field behavior and the transfer to third parties, who were awarded with contracts in the bidding rounds, of certain fields that had been temporarily assigned to PEMEX and associations and alliances such as Santuario and El Golpe fields, of which PEMEX is assigned a 64% of their proved reserves. The amount of dry gas reserves added in 2017 was insufficient to offset the level of production in 2017, which amounted to 999 billion cubic feet of dry gas. PEMEX’s proved undeveloped dry gas reserves increased by 3.9% in 2017, from 2,471 billion cubic feet at December 31, 2016 to 2,567 billion cubic feet at December 31, 2017.

During 2017, our exploratory activity in the shallow waters of the Gulf of Mexico and onshore regions resulted in new discoveries of light crude oil in the offshore Suuk field in June 2017 and gas and condensate discoveries in the onshore Valeriana and lxachi fields in August and November of 2017, respectively. These discoveries led to the incorporation of approximately 246 million barrels of oil equivalent in three fields.

The following three tables of crude oil and dry gas reserves set forth PEMEX’s estimates of its proved reserves determined in accordance with Rule 4-10(a).

Summary of oil and gas⁽¹⁾ proved reserves as of December 31, 2017

based on average fiscal year prices

	Crude oil and Condensates(2)		Dry Gas(3)
	(in millions of barrels)		(in billions of cubic feet)
Proved developed and un-developed reserves:
Proved developed reserves		4,166		4,026
Proved undeveloped reserves		2,261		2,567
Total proved reserves		6,427		6,593

Note: Numbers may not total due to rounding.

(1) PEMEX does not currently produce synthetic oil or synthetic gas, or other natural resources from which synthetic oil or synthetic gas can be produced.

(2) Crude oil and condensate reserves include the fraction of liquefiable hydrocarbons recoverable in natural gas processing plants located at fields.

(3) Reserve volumes reported in this table are volumes of dry gas, although natural gas production reported in other tables refers to sour wet gas. There is a shrinkage in volume when natural gas liquids and impurities are extracted to obtain dry gas. Therefore, reported natural gas volumes are greater than dry gas volumes.

Source: Pemex Exploration and Production.

Crude oil and condensate reserves

(including natural gas liquids)⁽¹⁾

	2017			2016			2015
	(in millions of barrels)
Proved developed and undeveloped reserves:
At December 31		7,219			7,977			10,292
Revisions(2)		(95	)		189			(1,491	)
Extensions and discoveries		147			(55	)		111
Production		(805	)		(891	)		(935	)
Farm outs & transfer of fields due to NHC bidding process		(38	)		—			—
At December 31		6,427			7,219			7,977
Proved developed reserves at December 31		4,166			4,886			5,725
Proved undeveloped reserves at December 31		2,261			2,333			2,252

Note: Numbers may not total due to rounding.

(1) Crude oil and condensate reserves include the fraction of liquefiable hydrocarbons recoverable in natural gas processing plants located at fields.

(2) Revisions include positive and negative changes due to new data from well drilling, revisions made when actual reservoir performance differs from expected performance and changes in hydrocarbon prices.

Source: Pemex Exploration and Production.

Dry gas reserves

	2017			2016			2015
	(in billions of cubic feet)
Proved developed and undeveloped reserves:
At December 31		6,984			8,610			10,859
Revisions(1)		169			(183	)		(955	)
Extensions and discoveries		468			(308	)		47
Production(2)		(999	)		(1,134	)		(1,341	)
Farm outs & transfer of fields due to NHC bidding process		(29	)		—			—
At December 31		6,593			6,984			8,610
Proved developed reserves at December 31		4,026			4,513			6,012
Proved undeveloped reserves at December 31		2,567			2,471			2,598

Note: Numbers may not total due to rounding.

(1) Revisions include positive and negative changes due to new data from well drilling, revisions made when actual reservoir performance differs from expected performance and changes in hydrocarbon prices.

(2) Production refers here to dry gas, although natural gas production reported in other tables refers to sour wet gas. There is a shrinkage in volume when natural gas liquids and impurities are extracted to obtain dry gas. Therefore, reported natural gas volumes are greater than dry gas volumes.

Source: Pemex Exploration and Production.

Pemex Exploration and Production’s reserve-replacement ratio, or RRR, for a given period is calculated by dividing the sum of proved reserves additions due to discoveries, developments, delineations and revisions by that period’s total production. During 2017, we obtained an increase of 174.2 million barrels of oil equivalent of proved reserves as aggregated from discoveries, revisions, delimitations and development and production, which represents a RRR of 17.5 %. PEMEX’s 2017 RRR is an improvement as compared to 2016, when the RRR was 4.0%. PEMEX expects continued improvements in its RRR in subsequent years.

PEMEX’s reserves production ratio, which is presented in terms of years, is calculated by dividing the estimated remaining reserves at the end of the relevant year by the total production of hydrocarbons for that year. As of December 31, 2017, this ratio stayed constant with 2016 levels and was equal to 7.7 years for proved reserves.

f. Standardized measure of discounted future net cash flows related to proved oil and gas reserves (unaudited)

The standardized measure tables presented below relate to proved oil and gas reserves excluding proved reserves scheduled to be produced after the year 2042. This measure is presented in accordance with ASC Topic 932.

Estimated future cash inflows from production are computed by applying average prices of oil and gas on the first day of each month of 2017. Future development and production costs are those estimated future expenditures needed to develop and produce the year-end estimated proved reserves after a net cash flows discount factor of 10%, assuming constant year-end economic conditions.

Future tax expenses are computed by applying the appropriate year-end statutory tax rates with consideration of the tax rates of the new fiscal regime for Pemex Exploration and Production already legislated for 2017 to the future pre-tax net cash flows related to PEMEX’s proved oil and gas reserves.

The estimated future payment of taxes was calculated based on fiscal regime applicable by decree to Pemex-Exploration and Production effective January 1, 2015 and by the tax benefits published in the Official Gazette of the Federation on April 18, 2016.

The standardized measure provided below represents a comparative benchmark value rather than an estimate of expected future cash flows or fair market value of PEMEX’s production rights. There are numerous uncertainties inherent in estimating quantities of proved reserves and in projecting future rates of production and timing of development expenditures, including many factors beyond the control of the producer. Accordingly, reserve estimates may be materially different from the quantities of crude oil and natural gas that are ultimately recovered.

Standardized measure of discounted future net cash flows as of December 31

	2017			2016			2015
	(in millions of U.S. dollars)
Future cash inflows	US$	269,489		US$	228,196		US$	325,052
Future production costs (excluding profit taxes)		(114,369	)		(87,942	)		(99,948	)
Future development costs		(26,229	)		(25,515	)		(32,560	)
Future cash flows before tax		128,891			114,738			192,544
Future production and excess gains taxes		(129,377	)		(108,960	)		(167,056	)
Future net cash flows		(487	)		5,779			25,488
Effect of discounting net cash flows by 10%		(4,600	)		(937	)		(9,946	)
Standardized measure of discounted future net cash flows	US$	4,113		US$	4,841		US$	15,541

Note: Table amounts may not total due to rounding.

To comply with ASC Topic 932, the following table presents the aggregate standardized measure changes for each of the last three years and significant sources of variance:

Changes in standardized measure of discounted future net cash flows

	2017			2016			2015
	(in millions of U.S. dollars)
Sales of oil and gas produced, net of production costs	US$	(25,076	)	US$	(19,411	)	US$	(28,371	)
Net changes in prices and production costs		26,355			(53,278	)		(327,865	)
Extensions and discoveries		3,639			1,105			3,086
Development cost incurred during the year		2,699			4,124			10,172
Changes in estimated development costs		2,744			1,763			(2,171	)
Reserves revisions and timing changes		(1,353	)		6,366			(22,801	)
Accretion of discount of pre-tax net cash flows		5,891			11,094			43,394
Net changes in production and excess gains taxes		(15,628	)		37,537			295,437
Aggregate change in standardized measure of discounted future net cash flows	US$	(728	)	US$	(10,700	)	US$	(29,119	)
Standardized measure:
As of January 1	US$	4,841		US$	15,541		US$	44,661
As of December 31		4,113			4,841			15,541
Change	US$	(728	)	US$	(10,700	)	US$	(29,119	)

Note: Table amounts may not total due to rounding.

In computing the amounts under each factor of change, the effects of variances in prices and costs are computed before the effects of changes in quantities. Consequently, changes in reserves are calculated at December 31 prices and costs.

The change in computed taxes includes taxes effectively incurred during the year and the change in future tax expense.

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Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2017

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Basis of consolidation

a. Basis of consolidation

The consolidated financial statements include those of Petróleos Mexicanos, the Subsidiary Entities and the Subsidiary Companies. All intercompany balances and transactions of the consolidated companies; income and expenses, as well as unrealized profits and losses resulting from operations between them have been eliminated in the preparation of the consolidated financial statements pursuant to IFRS 10, “Consolidated Financial Statements” (“IFRS 10”).

Unrealized gains arising from transactions with entities whose investment is accounted for using the equity method are eliminated against the investment to the extent of PEMEX’s participation in such entities. Unrealized losses are eliminated in the same way as unrealized gains but only to the extent that there is no evidence of impairment of the investment. If such evidence exists, PEMEX recognizes it in its consolidated financial statements.

Investment in subsidiaries

The Subsidiary Entities and Subsidiary Companies are consolidated from the date that control commences until the date that control ceases.

Petróleos Mexicanos controls a subsidiary when it is exposed to or has rights to variable returns from the company and has the ability to affect those returns through its power over the company.

The financial statements of the Subsidiary Entities and Subsidiary Companies have been prepared based on the same period of Petróleos Mexicanos’ consolidated financial statements applying the same accounting policies.

For more information about Subsidiary Companies, see Note 4.

Investments in associates and joint arrangements

Associates are those entities in which PEMEX has significant influence but not the power to control financial and operational decisions. It is presumed that there is significant influence when PEMEX owns directly or indirectly between 20% and 50% of voting rights in another entity.

Joint arrangements are those arrangements whereby two or more parties have joint control of an arrangement. A joint arrangement is either a joint venture, where both of the parties have rights to the net assets of the arrangements, or a joint operation, where the parties have both rights to the assets, and obligations for the liabilities relating to the arrangements.

Investments in associates and joint ventures are recognized based on the equity method and recorded initially at cost, including any goodwill identified on acquisition. With respect to joint operations, the assets, liabilities, income and expenses are recognized in relation to the share of each party and in accordance with the applicable IFRS for each of those items. The investment cost includes transaction costs.

These consolidated financial statements include the proportion of gains, losses and other comprehensive income corresponding to PEMEX’s share in each investee, once these items are adjusted to align with the accounting policies of PEMEX, from the date that significant influence and joint control begins to the date that such influence or joint control ceases.

When the value of the share of losses exceeds the value of PEMEX’s investment in an associate or joint venture, the carrying value of the investment, including any long-term investment, is reduced to zero and PEMEX ceases to recognize additional losses, except in cases where PEMEX is liable for obligations incurred by those associates and joint ventures.

For more information about associates and joint arrangements, see Note 11.

Non-controlling interests

The equity interests of third parties who do not have a controlling interest in the equity or comprehensive result of subsidiaries of PEMEX are presented in the consolidated statements of financial position, the consolidated statements of changes in equity (deficit) as “non-controllinginterests” and as “net income and comprehensive income for the period, attributable to non-controlling interests,” in the consolidated statements of comprehensive income.

Changes in a parent’s ownership interest in a subsidiary that do not result in a loss of control are accounted for as equity transactions. In such circumstances, the carrying amounts of the controlling and non-controlling interests shall be adjusted to reflect the changes in their relative interests in the subsidiary.

Dividends in cash and assets other than cash

A liability for distributions of dividends in cash and non-cash assets to third parties is recognized when the distribution is authorized by the Board of Directors. The corresponding amount is recognized directly in equity.

Distributions of dividends in non-cash assets are measured at the fair value of the assets to be distributed. Changes relating to these measurements of the fair value, between the date on which the distribution is declared and the date when the assets are transferred, are recognized directly in equity.

When distributing non-cash assets, any difference between the carrying amount of the liability for distribution of dividends and the carrying amount of the assets distributed is recognized in the consolidated statements of comprehensive income.

Business combinations and goodwill

b. Business combinations and goodwill

Business combinations are accounted for using the acquisition method. The cost of an acquisition is measured as the aggregate of the consideration transferred, measured as the acquisition date fair value, and the amount of any non-controlling interest in the acquiree.

When PEMEX acquires a business, it assesses the acquired assets and liabilities in order to appropriately classify and designate each, taking into account the contractual terms, economic circumstances and other pertinent conditions as of the date of the acquisition. This includes the separation of embedded derivatives in host contractors by the acquiree. Acquired petroleum reserves and resources that can be reliably measured are recognized separately in the assessment of fair values on acquisition. Other potential reserves and rights, for which fair values cannot be reliably measured, are not recognized separately, but instead are subsumed in goodwill.

For business combinations achieved in stages, any previously held equity interest is measured at its acquisition date fair value, and any resulting gain or loss is recognized in income or loss or other comprehensive income.

Any contingent consideration to be transferred by the acquirer will be recognized at fair value on the acquisition date. Contingent consideration classified as an asset or liability that is a financial instrument and within the scope of IAS 39 “Financial instruments: Recognition and Measurement” is measured at fair value, with changes in fair value recognized in income or loss or other comprehensive income. If contingent consideration is not with the scope of IAS 39, it is measured in accordance with the appropriate IFRS requirement. Contingent consideration that is classified as equity is not remeasured, and subsequent settlement is accounted for within equity.

Goodwill, which is initially measured at cost, is the excess of the aggregate of the consideration transferred and the amount recognized for non-controlling interest over the fair value of the identifiable net assets acquired and liabilities assumed. If the fair value of the net asset acquired is greater than the aggregate consideration transferred (bargain purchase), before recognizing a gain, PEMEX reassesses whether it has correctly identified all of the assets acquired and all of the liabilities assumed and reviews the procedures used to measure the amounts to be recognized at the acquisition date. If the assessment still results in an excess of the fair value of net assets acquired over the aggregate consideration transferred, then the gain is recognized in the consolidated statements of comprehensive income.

After initial recognition, goodwill is measured at cost less any accumulated impairment losses. For the purpose of impairment testing, goodwill acquired in a business combination is, from the acquisition date, allocated to each cash generating unit that is expected to benefit from the combination, irrespective of whether other assets or liabilities of the acquiree are assigned to those units.

When goodwill is allocated to a cash generating unit and certain of the operations in that unit are disposed of, the goodwill associated with the disposed operation is included in the carrying amount of the operation when determining the gain or loss on disposal. Goodwill disposed in these circumstances is measured based on the relative values of the disposed operation and the portion of the cash generating unit retained.

Transactions in foreign currency

c. Transactions in foreign currency

In accordance with IAS 21, “The Effects of Changes in Foreign Exchange Rates” (“IAS 21”), transactions in foreign currencies are translated and recorded at exchange rates at the dates of the transactions and/or of the presentation of financial information.

Exchange differences arising from the settlement of monetary items or from the translation of monetary items into rates different from those at which they were translated on their initial recognition, are recognized in the results of operations in the reporting period in which they arise. When a gain or loss from a non-monetary item is recognized in other comprehensive results, any exchange difference included in that gain or loss is recognized in other comprehensive results. Conversely, when a gain or loss from a non-monetary item is recognized in the results of operations, any exchange difference included in that gain or loss is recognized in the results of operations for the period.

Fair value measurement

d. Fair value measurement

PEMEX measures certain financial instruments such as DFIs at fair value as of the closing date of the relevant reporting period.

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. A measurement at fair value assumes that the sale of the asset or transfer of a liability occurs:

i. in the principal market for the asset or liability; or

ii. in the absence of a principal market, in the most advantageous market for the asset or liability.

The principal market or the most advantageous market must be accessible for PEMEX.

The fair value of an asset or liability is measured by using the same assumptions that market participants would make when pricing the asset or liability under the premise that market participants take into account highest and best use of the asset or liability.

Financial instruments

e. Financial instruments

Financial instruments are classified as: (i) financial instruments measured at fair value through profit or loss; (ii) financial instruments held to maturity; (iii) available-for-sale financial assets; (iv) investments in equity instruments; (v) loans and receivables; and (vi) DFIs. PEMEX determines the classification of its financial instruments at the time of initial recognition.

PEMEX’s financial instruments include cash and short-term deposits, available-for-sale financial assets, accounts receivable, other receivables, loans, accounts payable to suppliers, other accounts payable, borrowings and debts, as well as DFIs.

Below are descriptions of the financial instruments policies employed by PEMEX:

Financial instruments measured at fair value through profit or loss

A financial instrument is measured at fair value through profit or loss if it is classified as held for trading or designated as such upon initial recognition. Financial assets are designated at fair value through profit or loss if PEMEX manages such investments and makes purchase and sale decisions based on their fair value in accordance with PEMEX’s documented risk management or investment strategy. In addition, directly attributable transaction costs are recognized in the consolidated statements of comprehensive income for the year. These financial instruments are recognized at fair value and corresponding changes relating to dividend income are recognized in the consolidated statements of comprehensive income.

Available-for-sale financial assets

Available-for-sale financial assets are non-DFIs that are designated as available-for-sale or are not classified in any of the previous categories. PEMEX’s investments in certain equity securities and debt securities are classified as available-for-sale financial assets. Available-for-sale financial assets are recognized initially at fair value plus any directly attributable transaction costs.

Subsequent to initial recognition, available-for-sale financial assets are measured at fair value. In addition, any gains or losses associated with such instruments, as well as foreign exchange differences are recognized in other comprehensive results and presented in the fair value reserve in equity. When an investment is derecognized, any gains or losses accumulated in the equity are reclassified to profit or loss.

Sales and purchases of financial assets that require the delivery of such assets within a period of time established by market practice are recognized as of the negotiation date (the date on which PEMEX commits to purchase or sell the asset).

Loans and receivables

Loans and receivables are initially recognized at fair value. After initial recognition, loans and debt securities that bear interest are measured at amortized cost using the effective interest rate (“EIR”) method, less impairment losses.

The amortized cost is calculated based on any discount or premium on acquisition and fees and costs that are an integral part of the EIR method. Amortization of costs is included under the heading of financing cost in the consolidated statements of comprehensive income.

Derivative financial instruments

DFIs presented in the consolidated statements of financial position are carried at fair value. In the case of DFIs held for trading, changes in fair value are recorded in profit or loss; in the case of DFIs formally designated as and that qualify for hedging, changes in fair value are recorded in the consolidated statements of comprehensive income using cash flow or fair value hedge accounting, with gains or losses classified in accordance with the earnings treatment of the hedge transaction.

Embedded derivatives

PEMEX evaluates the potential existence of embedded derivatives, which may be found in the terms of its contracts, or combined with other host contracts, which could be structured financial instruments (debt or equity instruments with embedded derivatives). Embedded derivatives have terms that implicitly or explicitly meet the characteristics of a DFI. In some instances, these embedded derivatives must be segregated from the underlying contracts and measured, recognized, presented and disclosed as DFIs, such as when the economic risks and terms of the embedded derivative are not clearly and closely related to the underlying contract.

Impairment of financial assets

At each reporting date, PEMEX evaluates whether there is objective evidence that a financial asset or group of financial assets is impaired, in which case the value of the recoverable amount of the asset is calculated. A financial asset is impaired if objective evidence indicates that a loss event has occurred after the initial recognition of the asset, and that the loss event had a negative effect on the estimated future cash flows of the financial asset.

Objective evidence that a financial asset or group of assets is impaired includes significant financial difficulty of the issuer or obligor, a breach of contract, such as a default or delinquency in interest or principal payments; the lender, for economic or legal reasons relating to the borrower’s financial difficulty, granting to the borrower a concession that the lender would not otherwise consider; it becoming probable that the borrower will enter bankruptcy or other financial reorganization; the disappearance of an active market for that financial asset because of financial difficulties; or observable data indicating that there is a measurable decrease in the estimated future cash flows. Impairments by asset are:

Impairment of financial assets carried at amortized cost

The impairment of financial assets carried at amortized cost is measured as the difference between the assets carrying amount and the present value of estimated future cash flows (excluding future credit losses that have not been incurred) discounted at the financial asset’s original effective interest rate. The amount of the loss shall be recognized in profit or loss.

If, in a subsequent period, the amount of the impairment loss decreases and the decrease can be related objectively to an event occurring after the impairment was recognized, the impairment loss previously recognized shall be reversed in profit or loss.

Impairment in available—for—sale financial assets

In addition to the above-mentioned, a significant or prolonged decline in the fair value of an investment in an available—for—sale equity instrument is also objective evidence of impairment.

When there is objective evidence of the impairment of an asset, the accumulated loss recognized in other comprehensive income shall be reclassified from equity to profit or loss even though the financial asset has not been derecognized.

If, in a subsequent period, the impairment loss decreases, the reversal shall be reflected as a reversal in other comprehensive income.

Cash and cash equivalents

f. Cash and cash equivalents

Cash and cash equivalents are comprised of cash balances on hand, net of overdrafts, deposits in bank accounts, foreign currency reserves and instruments with maturities of three months or less from the acquisition date that are subject to an insignificant risk of changes in their fair value, which are used in the management of PEMEX’s short-term commitments.

Cash subject to restrictions or that cannot be exchanged or used to settle a liability within 12 months is presented as non-current assets.

Inventories and cost of sales

g. Inventories and cost of sales

Inventories are valued at the lower of cost or net realizable value. Cost is determined based on the cost of production or acquisition of inventory and other costs incurred in transporting such inventory to its present location and in its present condition, using the average cost formula. Net realizable value is the estimated selling price in the ordinary course of business less the estimated costs of completion and the estimated selling costs. The estimate takes into consideration, among other things, the decrease in the value of inventories due to obsolescence.

Cost of sales represents the cost of production or acquisition of inventories at the time of sale, increased, where appropriate, by declines in net realizable value of inventories during the year.

Advance payment to suppliers for inventory purchases are recognized as part of inventory when the risks and benefits of the ownership of the inventory have been transferred to PEMEX.

Wells, pipelines, properties, plant and equipment

h. Wells, pipelines, properties, plant and equipment

Wells, pipelines, properties, plant and equipment are recorded at acquisition or construction cost less accumulated depreciation and accumulated impairment losses.

PEMEX uses the successful efforts method for the exploration and production of crude oil and gas activities, considering the criteria mentioned in IFRS 6, “Exploration for and Evaluation of Mineral Resources” in relation to the recognition of exploration and drilling assets. Costs of development wells and related plant, property and equipment involved in the exploitation of oil and gas are recorded as part of the cost of assets. The costs of exploratory wells in areas that have not yet been designated as containing proved reserves are recorded as intangible assets until it is determined whether they are commercially viable to capitalize as fixed assets, otherwise they are recognized as exploration expenses. Other expenditures on exploration are recognized as exploration expenses as they are incurred.

In accordance with IAS 16, “Property, Plant and Equipment” (“IAS 16”), initial costs of wells, pipelines, properties, plant and equipment are initially recorded at cost, which includes their original purchase price or construction cost, any costs attributable to bringing the assets to a working condition for their intended use and the costs of dismantling and removing the items and restoring the site on which they are located, including the estimated cost of plugging and abandoning wells.

The cost of financing projects that require large investments and financing incurred for projects, net of interest revenues from the temporary investment of these funds, is recognized as part of wells, pipelines, properties, plant and equipment when the cost is directly attributable to the construction or acquisition of a qualifying asset. The capitalization of these costs is suspended during periods in which the development of construction is interrupted, and its capitalization ends when the activities necessary for the use of the qualifying asset are substantially completed. All other financing costs are recognized in the consolidated statements of comprehensive income in the period in which they are incurred.

The cost of self-constructed assets includes the cost of materials and direct labor, interest on financing and any other costs directly attributable to start up. In some cases the cost also includes the cost of plugging of wells and removal.

Expenditures related to the construction of wells, pipelines, properties, plant and equipment during the stage prior to commissioning are stated at cost as intangible assets or construction in progress, in accordance with the characteristics of the asset. Once the assets are ready for use, they are transferred to the respective component of wells, pipelines, properties, plant and equipment and depreciation or amortization begins.

The costs of major maintenance or replacement of a significant component of an item of wells, pipelines, properties, plant and equipment are recognized in the carrying amount of the item if it is probable that the future economic benefits embodied within the component will flow to PEMEX and its cost can be measured reliably. The costs of recurring maintenance, repairs and renovations of wells, pipelines, properties, plant and equipment carried out to maintain the facilities in normal operation conditions are recognized in profit or loss as incurred.

Depreciation and amortization of capitalized costs in wells are determined based on the estimated economic life of the field to which the wells belong, considering the relationship between the production of barrels of oil equivalent for the period and proved developed reserves of the field, as of the beginning of the period, with quarterly updates for new development investments.

Depreciation of other elements of pipelines, properties, plant and equipment is recognized in profit or loss on a straight-line basis over the estimated useful life of the asset, beginning as of the date that the asset is available for use, or in the case of construction, from the date that the asset is completed and ready for use.

When parts of an item of wells, pipelines, properties and equipment are significant relative to the total cost of the item, the part is depreciated separately.

Estimated useful lives of items of properties, plant and equipment are reviewed if expectations differ from previous estimates.

Pipelines, properties, and equipment received from customers are initially recognized at fair value as revenue from ordinary operating activities if PEMEX has no future obligations to the customer who transferred the item. In contrast, if PEMEX does have future obligations to such a customer, the initial recognition is recorded as a deferred liability based on the period in which the assets will provide services to the customers.

The capitalized value of finance leases is also included in the line item of wells, pipelines, properties, plant and equipment. Properties, plant and equipment acquired through financial leases are depreciated over the shorter of the lease term or the useful life of the asset.

Advance payments for the acquisition of pipelines, properties, plant and equipment are also recognized in the line item of wells, pipelines, properties, plant and equipment when the risks and benefits of the ownership have been transferred to PEMEX.

Crude oil and natural gas reserves

i. Crude oil and natural gas reserves

Under Mexican law, all crude oil and other hydrocarbon reserves located in the subsoil of Mexico are owned by the Mexican nation and not by PEMEX. In accordance with the aforementioned and based on the applicable regulation as of the date of these consolidated financial statements, the reserves assigned to PEMEX by the Mexican Government are not registered for accounting purposes because they are not PEMEX’s property. PEMEX estimates total proved oil and natural gas reserve volumes in accordance with the definitions, methods and procedures established in Rule 4-10(a) of Regulation S-X (“Rule 4-10(a)”) of the U.S. Securities and Exchange Commission (“SEC”) as amended, and where necessary, in accordance with the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers (the “SPE”) as of February 19, 2007. These procedures are consistent with international reserves reporting practice. The estimation of these reserves depends on assumptions made and the interpretation of the data available, and may vary among analysts. The results of drilling activities, test wells and production after the date of estimation are utilized in future revisions of reserves estimates.

Although PEMEX does not own the oil and other hydrocarbon reserves within Mexico, these procedures allow PEMEX to record the effects that such oil and other hydrocarbon reserves have on its consolidated financial statements, including, for example, in the depreciation and amortization line item.

Impairment of non-financial assets

j. Impairment of non-financial assets

The carrying amounts of PEMEX’s non-financial assets, other than inventories and deferred taxes, are assessed for indicators of impairment at the end of each reporting period. If the net carrying value of the asset or its cash-generating unit exceeds the recoverable amount, PEMEX records an impairment charge in its consolidated statement of comprehensive income.

A cash-generating unit is the smallest identifiable group of assets which can generate cash flows independently from other assets or groups of assets.

The recoverable amount of an asset or a cash-generating unit is defined as the higher of its fair value minus the costs of disposal and its value in use. The value in use is the discounted present value of the net future cash flows expected to arise from the continuing use of an asset and from its disposal at the end of its useful life. In measuring value in use, the discount rate applied is the pre-tax rate that reflects current market assessments of the time value of money and the risks specific to the asset. Fair value is calculated using discounted cash flows determined by the assumptions that market participants would apply in order to estimate the price of an asset or cash generating unit, assuming that such participants were acting in their best economic interest.

In the case of cash-generating assets or items dedicated to the exploration and evaluation of hydrocarbons reserves, the recoverable amount is determined using the value in use based on the proved reserves and probable reserves, in some cases, for the risk factor associated with such reserves.

Both impairment losses and reversals are recognized in the statement of comprehensive income in the costs and expenses line items in which the depreciation and amortization are recognized. Impairment losses may not be presented as part of the costs that have been capitalized in the value of any asset. Impairment losses related to inventories are recognized as part of cost of sales. Impairment losses on investments in associates, joint ventures and other investments are recognized as profit (loss) sharing in associates.

An impairment loss shall be reversed if there has been a change in the estimates used since the date when the impairment loss was recognized. These reversals will not exceed the carrying value of the asset as though no impairment had been recognized. Impairment losses and reversals are presented in a separate line item in the statement of comprehensive income.

Leases

k. Leases

The determination of whether an agreement is or contains a lease is based on the economic substance of the agreement at the date of execution. An agreement contains a lease if performance under the agreement depends upon the use of a specific asset or assets, or if the agreement grants the right to use the asset.

Finance leases, which transfer to PEMEX substantially all the inherent benefits and risks of the leased property, are capitalized at the date the lease commences, and the value is recorded as the lower of the fair value of the leased property and the present value of the minimum lease payments. Payments on the lease are divided between the financial costs and the amortization of the remaining debt principal in order to achieve a constant effective interest rate for the outstanding liability. The financing costs are recognized in the statement of comprehensive income.

Operating lease payments are recognized as expenses in the statement of comprehensive income on a straight line basis over the term of the lease and variable rent payments are recognized in the operating results on an accrued basis.

Provisions

l. Provisions

PEMEX recognizes provisions when, as a result of a past event, PEMEX has incurred a legal or assumed present obligation for which a future disbursement is probable and the value of such disbursement is reasonably estimable. In certain cases, such amounts are recorded at their present value.

Environmental liabilities

In accordance with applicable legal requirements and accounting practices, an environmental liability is recognized when the cash outflows are probable and the amount is reasonably estimable. Disbursements related to the conservation of the environment that are linked to revenue from current or future operations are accounted as expenses or assets, depending on the circumstances of each disbursement. Disbursements related to past operations, which no longer contribute to current or future revenues, are accounted for as current period expenses.

The accrual of a liability for a future disbursement occurs when an obligation related to environmental remediation, for which PEMEX has the information necessary to determine a reasonable estimated cost, is identified.

Retirement of assets

The obligations associated with the future retirement of assets, including those related to the retirement of wells, pipelines, properties, plant and equipment and their components are recognized at the date that the retirement obligation is incurred, based on the discounted cash flow method. The determination of the fair value is based on existing technology and regulations. If a reliable estimation of fair value cannot be made at the time the obligation is incurred, the accrual will be recognized when there is sufficient information to estimate the fair value.

The obligations related to the costs of future retirement of assets associated with the principal refining processes for gas and petrochemicals are not recognized. These assets are considered to have an indefinite useful life due to the potential for maintenance and repairs.

The abandonment costs related to wells currently in production and wells temporarily closed are recorded in the statement of comprehensive income based on the units of production method. Total cost of abandonment and plugging for non-producing wells is recognized in the statement of comprehensive income at the end of each period. All estimations are based on the useful lives of the wells, considering their discounted present value. Salvage values are not considered, as these values commonly have not traditionally existed.

Employee benefits

m. Employee benefits

Beginning January 1, 2016, Petróleos Mexicanos and the Subsidiary Entities have operated both a defined contribution plan and a defined benefit pension plan. Until December 31, 2015, PEMEX only operated a defined benefit pension plan.

Defined contribution pension plan

In this plan, both Petróleos Mexicanos and the Subsidiary Entities and their respective employees contribute to the worker’s individual account. PEMEX’s contributions are recognized on an accrual basis as cost, expense or asset, and are credited to liability.

Contributions to the defined contribution plan that are not expected to be fully settled within 12 months after the end of the annual reporting period in which the employee rendered related services will be discounted using the defined benefit plan discount rate.

Defined benefit plan

Under the defined benefit plan, Petróleos Mexicanos and the Subsidiary Entities are the only parties that contribute to a trust, which is managed separately. Petróleos Mexicanos and the Subsidiary Entities recognize the cost for defined benefit plans based on independent actuarial computations applying the projected unit credit method. Actuarial gains and losses are recognized within other comprehensive results for the period in which they are determined.

The costs of prior services are recognized within profit or loss for the period in which they are determined.

The asset or liability in the defined benefit plan comprises the present value of the defined benefit obligation less the fair value of plan assets for which obligations have to be settled. The value of any asset is limited to the present value of any economic benefit represented by the plan reimbursements or reductions of the future contributions to the plan.

In addition, other long term employee benefits include the seniority premiums payable for disability, death and survivors benefits, medical services, gas and basic food basket for beneficiaries.

Termination benefits are recognized in profit or loss for the year in which they are incurred.

Income taxes and duties

n. Income taxes and duties

Current income tax

Current income tax assets or liabilities for the current and prior years are measured as the amount expected to be paid or to be recovered from the tax authorities, using either the tax rates in force or tax rates which are in the process of being approved and are substantially completed by the end of the year.

Current income taxes related with items that are recognized as equity are presented in the other comprehensive income of the year. Periodically, PEMEX evaluates the positions taken in its tax returns for those regulations that are subject to interpretation and books corresponding provisions, if it is deemed necessary.

Deferred income taxes

Deferred taxes are recorded based on the assets and liabilities method, which consists of the recognition of deferred taxes by applying tax rates applicable to the income tax to the temporary differences between the carrying value and tax values of assets and liabilities at the date of these consolidated financial statements.

Deferred tax liabilities are recognized for all taxable temporary differences, except to the extent that the deferred tax liability arises from:

• the initial recognition of goodwill or the initial recognition of an asset or liability in a transaction which is not a business combination and at the time of the transaction, affects neither accounting profit nor taxable profit or tax loss; and

• taxable temporary differences associated with investments in subsidiaries, branches and associates, and interest in joint arrangements, when the parent, investor, joint venture or joint operator is able to control the timing of reversal of the temporary difference and it is probable that the temporary difference will not reverse in the foreseeable future.

Deferred tax assets are recognized for all deductible temporary differences and the carry forward of both unused tax credits and unused tax losses to the extent that it is probable that taxable profit will be available against deductible temporary differences, and that the carry forward of both unused tax credits and unused tax losses can be utilized, unless:

• the deferred tax asset relating to deductible temporary difference arises from the initial recognition of asset or liability derived from a transaction that is not a business combination and, at the time of the transaction, affects neither accounting profit nor taxable profit or tax loss; and

• in respect of deductible temporary differences associated with investments in subsidiaries, associates and interests in joint ventures, deferred tax assets are recognized only to the extent that it is probable that the temporary differences will reverse in the foreseeable future and taxable profit will be available, against which the temporary differences can be utilized.

The carrying amount of a deferred tax asset is reviewed at the end of each reporting period. PEMEX reduces the carrying amount of a deferred tax asset to the extent that it is no longer probable that a sufficient taxable profit will be available to allow the benefit of that deferred tax asset to be utilized in whole or in part. Unrecognized deferred tax assets are revalued at each reporting date and will be recognized to the extent that it is probable that future taxable income will be sufficient to allow for the recovery of the deferred tax asset.

Deferred tax assets and liabilities are measured at the tax rates that are expected to apply to the period when the asset is realized or the liability is settled, based on tax rates (and tax laws) that have been enacted or substantively enacted by the end of the reporting period.

Deferred tax assets and deferred tax liabilities related with items that are recognized in equity shall be presented directly in other comprehensive income.

Deferred tax assets and deferred tax liabilities are offset if PEMEX has a legal right to set off current tax assets against current tax liabilities and are levied by the same taxation authority or the same taxable entity.

Income taxes and duties

PEMEX is subject to taxes and special duties, which are based on the value of hydrocarbons extracted, with certain deductions.

These taxes and duties are recognized in accordance with IAS 12, “Income Taxes” (IAS 12), when they have the characteristics of income tax, which occurs when such taxes are set by a government authority and are determined on a formula that considers the balance of income (or extraction valued at a selling price) less expenses. Taxes and duties that meet this criteria should be recognized for current and deferred income tax based on the above paragraphs. Taxes and duties that do not meet this criteria are recognized as liabilities, affecting the costs and expenses relating to the transactions that gave rise to them.

Impuesto Especial sobre Produccion y Servicios

o. Impuesto Especial sobre Producción y Servicios

(Special Tax on Production and Services, or “IEPS Tax”)

The IEPS Tax charged to customers is a withholding tax on domestic sales of gasoline, diesel and fossil fuels. The applicable quotas depend on, among other factors, the product, producer’s price, freight costs, commissions and the region in which the respective product is sold. The withholding tax does not affect the results of PEMEX.

Contingencies

p. Contingencies

Contingency losses are recorded when it is probable that a liability has been incurred and the amount thereof can be reasonably estimated. When a reasonable estimation cannot be made, qualitative disclosure is provided in the notes to the consolidated financial statements. Contingent revenues, earnings or assets are not recognized until realization is assured.

Revenue recognition

q. Revenue recognition

Sales revenue is recognized at the moment when the risks and benefits of ownership of crude oil, refined or gas products, and derivative and petrochemical products are transferred to the customers who acquire them, which occurs as follows:

• in accordance with contractual terms;

• the moment at which the customer picks up product at PEMEX’s facilities; or

• the moment at which PEMEX delivers the product to the delivery point.

Services rendered are recognized as services income when the customers accept the receipt of the services.

Presentation of consolidated statements of comprehensive income

r. Presentation of consolidated statements of comprehensive income

The costs and expenses shown in PEMEX’s consolidated statements of comprehensive income are presented based on their function, which allows for a better understanding of the components of PEMEX’s operating income. This classification allows for a comparison to the industry to which PEMEX belongs.

Revenues

Represents revenues from sale or products or services.

Cost of sales

Cost of sales represents the acquisition and production costs of inventories at the time of sale. Cost of sales mainly includes depreciation, amortization, salaries, wages and benefits, a portion of the cost of the reserve for employee benefits and operating expenses related to the production process.

Other revenues (expenses), net

Other revenues (expenses), net consist primarily of income and expenses that are not related directly to the operation of PEMEX.

Transportation, distribution and sale expenses

Transportation, distribution and sale expenses are costs in connection with the storage, sale and delivery of products, such as the depreciation and operating expenses associated with these activities.

Administrative expenses

Administrative expenses are costs related to PEMEX’s areas that provide administrative support.

Financing income

Financing income is comprised of interest income, financial income and other income from financial operations between PEMEX and third parties.

Financing cost

Financing cost is comprised of interest expenses, commissions and other expenses related to PEMEX’s financing operations less any portion of the financing cost that is capitalized.

Derivative financial instruments (cost) income, net

Derivative financial instruments (cost) income represents the net effect of the profit or loss for the year associated with DFIs.

Foreign exchange loss, net

Exchange rate variations relating to assets or liabilities governed by contracts denominated in foreign currencies are recorded in income (loss) for the year.

Operating segments

s. Operating segments

Operating segments are identifiable components of PEMEX that pursue business activities from which PEMEX earns revenues and incurs expenses, including those revenues and expenses from transactions with other segments of PEMEX, and for which information is available to management on a segmented basis and is assessed by the Board of Directors in order to allocate resources and assess the profitability of the segments.

Non-current assets held for sale, non-current assets held for distribution to owners and discontinued operations

t. Non-current assets held for sale, non-current assets held for distribution to owners and discontinued operations

Non-current assets held for sale

PEMEX classifies a non-current asset, or a disposal group of assets, as held for sale if (a) its carrying amount will be recovered principally through a sale transaction rather than through continuing use; (b) the asset or group of assets is available in its present condition for immediate sale and (c) the sale is expected to be completed within one year from the date of classification, or more, with certain exceptions.

Non-current assets classified as held for sale are measured at the lower of its carrying amount, and fair value less cost of sales and presented in a separate line item in the consolidated statements of financial position. Non-current assets classified as held for sale are not subject to depreciation or amortization after the classification as held for sale.

The liabilities of a disposal group classified as held for sale are presented separately from other liabilities in the statement of financial position. Those assets and liabilities are not offset and are presented as a single amount.

Non-current asset held for distribution to owners

When PEMEX agrees to distribute a non-current asset, or a disposal group of assets, to owners, this asset or disposal group of assets, is classified as held for distribution to owners if: a) a non-current asset or disposal group of assets is available for immediate distribution in its present condition and b) the distribution must be highly expected to be completed within one year from the date of classification, with certain exceptions.

Non-current assets classified as held for distribution are measured at the lower of their carrying amount and fair value less cost of distribution and are presented in a separate line item in the consolidated financial statements. Non-current assets classified as held for distribution are not subject to depreciation or amortization after the classification as held for distribution.

The liabilities of a disposal group classified as held for distribution to owners are presented separately from other liabilities in the statement of financial position. Those assets and liabilities shall not be offset and shall be presented as a single amount.

Discontinued operations

A discontinued operation is a component of an entity that either has been disposed of or is classified as held for sale, and either:

• represents a separate major line of business or geographical area of operations;

• is part or a single coordinated plan to dispose of a separated major line of business or geographical area of operations; or

• is a subsidiary acquired exclusively with a view to resale.

The revenues or expenses from discontinued operations, including profits or losses from previous years, are presented in a specific line item in the consolidated statements of comprehensive income.

Accounting changes

u. Accounting changes

The IASB issued new amendments to the IFRS mentioned below, which are applicable to PEMEX and are effective for annual periods beginning January 1, 2017:

a) IAS 12 “Income Taxes: Recognition of Deferred Tax Assets for Unrealized Losses” (“IAS 12”)

The IASB issues amendments to IAS 12 to clarify the diversity of practices in the recognition of deferred tax assets for unrealized losses related to debt instruments measured at fair value.

The amendments to IAS 12 include some explanatory paragraphs and an illustrative example.

The amendments clarify the following aspects of IAS 12:

• Unrealized losses on debt instruments measured at fair value for accounting purposes and measured at cost for tax purposes give rise to deductible temporary differences regardless of whether the debt instrument’s holder expects to recover the carrying amount of the debt instrument by sale or by use.

• The carrying amount of an asset does not limit the estimation of probable future taxable profits.

• Estimates of future taxable profits exclude tax deductions resulting from the reversal of deductible temporary differences.

• An entity assesses a deferred tax asset in combination with other deferred tax assets. Where tax law restricts the utilization of tax losses, an entity would assess a deferred tax asset in combination with other deferred tax assets of the same type.

The amendments are to be applied retrospectively and are effective for annual periods beginning on or after January 1, 2017. Earlier application is permitted.

These amendments had no impact on these consolidated financial statements.

b) Amendments to IAS 7 “Statement of Cash Flows” (“IAS 7”)

The IASB issued amendments to IAS 7. The amendments are intended to clarify disclosure provided to the user of financial statements about an entity’s financing activities.

Changes

The amendments in IAS 7 come with the objective that entities shall provide disclosures that enable users of financial statements to evaluate changes in liabilities arising from financing activities.

To achieve this objective, the IASB requires that the following changes in liabilities arising from financing activities are disclosed: (i) changes from financing cash flows; (ii) changes arising from obtaining or losing control of subsidiaries or other businesses; (iii) the effects of changes in foreign exchange rate; (iv) changes in fair values; and (v) other changes.

The IASB defines liabilities arising from financing activities as liabilities “for which cash flows were, or future cash flows will be, classified in the statements of cash flows as cash flows from financing activities.” It also stresses that the new disclosure requirements also relate to changes in financial assets if they meet the same definition.

The amendments state that one way to fulfill the new disclosure requirements is to provide reconciliation between the opening and closing balances in the statement of financial position for liabilities arising from financing activities.

Finally, the amendments state that changes in liabilities arising from financing activities must be disclosed separately from changes in other assets and liabilities.

The amendments are effective for annual periods beginning on or after January 1, 2017. Earlier application is permitted. Entities need not provide comparative information when they first apply the amendments.

Impacts on this amendments are disclosed in Note 15.

c) IFRS 12 “Disclosure of Interest in Other Entities” (“IFRS 12”)—Annual Improvements to IFRS 2014—2016 Cycle.

As of December 2016, the IASB published Annual Improvements to IFRS 2014—2016 Cycle, which clarified the scope of IFRS 12, by specifying that the disclosure requirements apply to all subsidiaries, joint arrangements, associates and unconsolidated structured entities classified as held for sale, held for distribution or as discontinued operations in accordance with IFRS 5, with certain exceptions.

The amendments are going to be applied restrospectively and are effective for annual periods beginning on or after January 1, 2017.

These improvements had no impact on these consolidated financial statements.

New accounting policies not yet adopted

v. New IFRS not yet adopted

The IASB issued amendments and new IFRS that are not effective as of December 31, 2017 but that could have an impact on subsequent PEMEX financial statements.

Amendments effective for periods beginning in 2018:

a) IFRS 15, “Revenue from Contracts with Customers” (“IFRS 15”)

The core principle of the new IFRS 15 is that an entity should recognize revenue as the promised transfer of goods or services to the customer, valued at the amount that the entity expects to be entitled in exchanged for those goods or services.

Pursuant to IFRS 15, an entity should:

• identify customer contracts that fall within the scope of the new standard;

• identify the separate performance obligations in the contract based on the following criteria: (i) sales of goods or services, separately, (ii) sales that are dependent or interrelated with other products or services; and (iii) homogeneous and consistent sales pattern;

• determine the price of the transaction by applying the following considerations: (i) variable consideration and constraining estimates of variable consideration; (ii) the existence of a significant financing component in the contract; (iii) any non-cash consideration; and (iv) the consideration payable to the customer;

• allocate the transaction price to each separate performance obligation; and

• recognize revenue when (or as) each performance obligation is satisfied either over time or at a point in time.

The new IFRS 15 enhances disclosures of revenue. This standard must be applied for periods beginning on or after January 1, 2018, and early application is permitted. During the year of application, entities may apply the rule retrospectively or use a modified approach.

PEMEX will adopt IFRS 15 retrospectively with the cumulative effect of applying the new standard recognized at the date of initial adoption (January 1, 2018) as an adjustment to the opening balance of retained earnings or other component of equity, as applicable. Under this transition method, PEMEX elected to apply this standard retrospectively only to contracts that were not completed contracts at January 1, 2018. For contracts that have been completed before December 31, 2017, with revenues not fully recognized as of that date, the current accounting policies under IAS 18 will continue to apply when recognizing revenue of those contracts during 2018. For contracts that take effect from January 1, 2018, revenue will be recognized in accordance with IFRS 15.

As part of the implementation of IFRS 15, different types of revenue from contracts with customers have been identified, evaluated and documented, as well as the main changes in accounting policies that will be reflected as of January 1, 2018 with respect to new contracts. The main changes in accounting policies are as follows:

i. Sale of products with other services:

The adoption of IFRS 15 will affect the manner in which PEMEX records the sale of products including oil, refined products, gas, petrochemicals, fertilizers and other sales. Until December 31, 2017, freight and other services, for example were recognized separately from products sold. Under IFRS 15, revenue is recognized with respect to the performance obligation under the contract, and so certain services that are currently accounted for separately, will now be presented as a single performance obligation together with the sale of the product.

ii. Services:

Services include transportation and storage of hydrocarbons, petroleum, petrochemicals, refined products, gas, petrochemical derivatives and others.

Rental services and some transportation services are currently presented in the revenues from services line item in the income statement. In many cases of services with components of leases are less than one year operating leases. Revenues corresponding to leasing have not been presented separately from revenues from services.

Under IFRS 15, leases cannot be presented in the same line item as revenues from service. The main change in accounting policy will be the separation and presentation of service and lease components.

iii. Determination of the transaction price:

Refunds, discounts, quantity and quality claims (in favor or against) and penalties (to customers or PEMEX) or breaches related to the sale of certain products were previously recognized as revenues. However, under IFRS 15, revenues will only be recognized if it is highly probable that there will not be a significant reversal in the revenue received. As a result, PEMEX will put in place mechanisms to approximate the refunds, discounts, quantity and quality claims and penalties at the time that the control of the product is transferred.

Revenue recognition

Revenues are currently recognized when the risks and benefits of the product are transferred, which occurs when the customer picks up or receives the product at PEMEX´s facilities or at a specific point of sale, accepts the products and assumes the risks and benefits related to the transfer of ownership.

Under IFRS 15, revenues from sale of products are recognized when the contractual obligation is satisfied, and control of the products is transferred to the customer. There will be changes in the revenue recognition of gas sale and certain services from “one point in time” to “over time”. However, a significant change is not expected because in some cases the practical expedient “right to invoice” will be applied to measure progress towards completion of the transaction.

As of December 31, 2017, PEMEX did not identify any significant uncompleted contracts. As a result, PEMEX has determined that the changes to amounts in prior years will not be significant. Nonetheless, there will be important changes in accounting policies for contracts issued as of January 1, 2018.

b) IFRS 9, “Financial Instruments” (“IFRS 9”(2014))

In July 2014, the IASB finalized the accounting reform of financial instruments and issued IFRS 9 (revised in 2014), which contains the requirements for, a) the classification and measurement of financial assets and liabilities, b) impairment methodology, and c) general information about hedge accounting. IFRS 9 (revised in 2014) replaces IAS 39 Financial Instruments: Recognition and Measurement as of its effective date.

These requirements should be applied retrospectively and, as permitted by IFRS 9 transitional provisions, it is not necessary for companies to restate comparative figures. Any adjustment in the carrying amounts of the financial assets and liabilities at the transition date is recognized by affecting the cumulative effect in the initial opening period.

The classification criteria depends on a combination of two important factors:

i. the business model within the financial asses is held (the business model test); and

ii. the contractual cashflow of the financial asset (the SPPI test). Based on these two tests, the asset can be measured as follows:

• Amortized cost: Financial Instruments under a business model whose objective is only the collection of contractual cash flows which are composed of principal and interest payments and where there are no significant sales unjustified and fair value is not a key factor in the management of these financial assets and the characteristics of cash flows represent substantially a “basic loan agreement” or SPPI. Unjustified sales are different from sales related to an increase in the credit risk of an asset or unexpected financing needs.

• Fair value with changes through other comprehensive income (“FVOCI”): Financial Instruments in a business model whose objective is to obtain cash flows and the sale of those assets, where fair value is a key factor in its management. In addition, the characteristics of the contractual cash flows represent substantially a “basic loan agreement”.

• Fair value with changes through profit or loss (“FVPL”): Financial instruments in a business model whose objective is not the aforementioned models, where fair value is a key factor in the management of these assets, and the financial instruments whose contractual cash flow characteristics do not substantially represent a “basic loan agreement”.

IFRS also replaces the impairment model of IAS 39 (the “loss incurred model”) with a new impairment model called the “expected credit loss” model. This impairment model will be applicable to financial assets that are not measured at FVPL. Changes in fair value of financial assets through FVOCI to the point of disposal are recorded in OCI.

The expected credit loss recognized for impairment purposes under IFRS 9 will be equivalent to a 12-month reserve, except when the financial instrument presents a “significant increase in credit risk” or presents objective evidence of impairment, recognizing a reserve equivalent to the remaining life of the financial instrument, based on the definition of general approach under IFRS 9.

IFRS 9 Implementation and government strategy

PEMEX has established a multidisciplinary working group with the objective to adapt its processes to the new standard in relation to the classification and measurement of financial instruments and the impairment estimation of credit risk, ensuring that these processes have been applied and adopted in accordance with IFRS 9.

Regarding classification and measurement, PEMEX carried out an analysis of its financial assets in order to identify those that could trigger a change in the accounting methodology, due to the definition of the business model and a failure to satisfy the SPPI test.

IFRS 9 Implementation analysis

PEMEX has defined January 1, 2018 as the initial date of adoption of IFRS 9 “Financial Instruments” and according to the transitional standard in IFRS 9, PEMEX will not restate previous periods for comparison purposes and any difference that may arise as a result of the adoption of IFRS 9 between the previous carrying amount and the carrying amount at the beginning of the reporting period shall be recognized in accumulated results over the opening initial period.

PEMEX has concluded that most of its financial assets will continue to be classified in the same way:

	Classification
Assets	IAS 39	IFRS 9	Change
Cash and cash equivalents	FVPL	FVPL		No
Available—for—sale financial assets	FVOCI	FVOCI		No
Derivative financial instruments	FVPL	FVPL		No
Long—term notes receivable	Amortized Cost	Amortized Cost		No

Capital or debt instruments classified as available-for-sale financial assets will continue to be measured at FVOCI.

PEMEX has concluded that the financial assets most affected by the impairment estimate under the expected credit loss model will be its accounts receivables, in relation to PEMEX’s holding of the long-term notes issued by the Mexican Government. The evaluation of the possible impairment of the notes will be made using the general approach for calculating impairment of the notes will be made using the general approach for calculating impairment contemplated under IFRS 9.

PEMEX considers it probable that impairment losses increase and present more volatility for instruments under the new methodology of expected credit losses. Furthermore, PEMEX considers that most of its accounts receivable are short-term without a significant financial component, so the simplified approach will be applied.

The preliminary evaluation of PEMEX indicates that the application of the new impairment requirements of IFRS 9 as of December 31, 2017 will impact the accounts receivable reserves as of January 1, 2018. An increase between 39.0% and 51.1% is expected in the accounts receivable reserves as compared to impairment losses incurred in accordance with IAS 39.

Hedge accounting

PEMEX, as part of the initial adoption, elected to continue applying the hedge accounting requirements of IAS 39 instead of IFRS 9. PEMEX uses DFI’s to cover the exposure of foreign currency risk, interest rate risk and fluctuations in the price of its products, but these contracts are not accounted for as designated hedges. DFI’s are initially recognized at fair value on the date the derivative contract is entered into and after initial recognition are measured again at fair value.

As a result, PEMEX has determined that the changes to amounts in prior years will not be significant.

c) Interpretation of IFRIC 22 “Foreign Currency Transactions and Advance Considerations” (IFRIC 22)

As of December 2016, IASB published an interpretation of IFRIC 22 developed by the International Financial Reporting Standards Interpretations Committee (the Interpretations Committee). The interpretation clarified when to recognize payments and collections of foreign currency transactions paid in advance.

According to the interpretations, an entity must recognize foreign currency transactions when:

i. there is consideration that is denominated or priced in a foreign currency;

ii. the entity recognizes a prepayment asset or a deferred income liability in respect of that consideration, in advance of the recognition of the related asset, expense or income; and

iii. the prepayment asset or deferred income liability is non-monetary.

The Interpretations Committee concluded that:

• The date of the transaction, for the purpose of determining the exchange rate, is the date of initial recognition of the non- monetary prepayment asset or deferred income liability.

• If there are multiple payments or receipts in advance, a date of transaction is established for each payment or receipt.

IFRIC 22 is effective for annual reporting periods beginning on or after January 1, 2018. Entities may apply the rule retrospectively, or prospectively, in accordance with IAS 8 with certain exemptions.

PEMEX believes that these standards will not have an impact on its consolidated financial statements.

Standards effective for periods beginning in 2019

a) IFRS 16, “Leases” (“IFRS 16”)

In January 2016, the IASB published a new accounting standard IFRS 16, which replaces IAS 17, “Leases and Guide interpretations.”

The main changes from the previous standard are:

• IFRS 16 provides a comprehensive model for the identification of the lease arrangements and their treatment in the financial statements of both lessees and lessors;

• the new standard applies a control model to the identification of leases, distinguishing between leases and service contracts on the basis of whether there is an identified asset controlled by the customer;

• the distinction between financial and operating leasing is removed, therefore, the assets and liabilities are recognized in respect of all leases, with some exceptions for short-term leases and leases of low-value assets; and

• the standard does not include significant changes to the requirements for accounting by lessors.

The standard is effective for annual periods beginning on or after January 1, 2019, with earlier application permitted for entities that have also adopted IFRS 15, “Revenue from Contracts with Customers.”

PEMEX has established a multidisciplinary working group with the objective to adapt its processes to the new standard in the following phases: (i) training, (ii) obtaining information, (iii) diagnostic, (iv) determination of initial adjustments and (v) integration of change. As of the date of these consolidated financial statements, the training phase for the accounting staff is complete and PEMEX is in the process of analyzing leasing contracts in order to determine necessary changes to its procedures and reports. PEMEX has not determined the impact of IFRS 16 on its net income (loss) for the year. PEMEX estimates that it will conclude the implementation of IFRS 16 in February 2019.

b) Annual improvements—2015-2017 Cycle

In December 2017, the IASB published “the Annual Improvements to the IFRS of the 2015-2017 Cycle” through which it clarifies the following IFRS:

• IFRS 3 Business Combinations and IFRS 11 Joint Arrangements

IFRS 3 Business Combinations clarifies how an entity should recognize an increase of its interest in a joint operation:

• When a party to a joint arrangement obtains control of a business that was a part of that joint arrangement, and where that party had assumed a portion of the rights to the assets and obligations to the liabilities of that business prior to the acquisition date, the acquisition will be considered a business combination that is achieved in stages. The acquiriting entity must therefore apply the requirements for a business combination achieved in stages, including by measuring its previously held interest in the joint arrangement.

• When a party participates in, but does not share in the control of a joint operation, and subsequently takes joint control of that joint operation, this will constitute the acquisition of a business and previously held interest in the joint operation are not measured.

• IAS 12 Income Tax

All income tax consequence of dividends (including payments on financial instruments classified as equity) are recognized consistently with the transactions that generated the distributable profits (i. e. in profit or loss, other comprehensive income or equity basis).

• IAS 23 Borrowing Costs

With respect to the treatment of costs for loans subject to capitalization, the amendments clarify that:

• To the extent that an entity borrows funds generally and uses them for the purpose of obtaining a qualifying asset, that entity shall determine the amount of borrowing costs eligible for capitalization by applying a capitalization rate to the expenditures on that asset. The capitalization rate shall be the weighted average of the borrowing costs applicable to all borrowings of the entity that are outstanding during the period.

• However, an entity shall exclude from this calculation borrowing cost applicable to borrowing made specifically for the purpose of obtaining a qualifying asset until substantially all the activities necessary to prepare that asset for its intended used or sale are complete.

The amount of borrowing costs that an entity capitalizes during a period shall not exceed the amount of borrowing costs it incurred during that period.

The amendments are effective for annual periods beginning on or after January 1, 2019.

PEMEX is in the process of evaluating the impact that these amendments will have on its consolidated financial statements.

c) IFRIC 23—Uncertainty over Income Tax Treatments

In June 2017, the IASB published a new accounting interpretation to be applied to the determination of taxable profit (tax loss), tax bases, unused tax losses, unused tax credits and tax rates, where there is uncertainty over income tax treatments under IAS 12.

In order to make these tax assessments, an entity must consider whether it is probable that the relevant taxing authority will accept each tax treatment, or group of tax treatments, that the entity has used or plans to use in its next income tax filing:

• If the entity concludes that it is probable that a particular tax treatment will be accepted by the relevant taxing authority, that entity must determine taxable profit (tax loss), tax bases, unused tax losses, unused tax credits or tax rates consistently with the tax treatment included in its income tax filings.

• If the entity concludes that it is not probable that a particular tax treatment is accepted by the relevant taxing authority, the entity must use the most likely amount or the expected value of the tax treatment when determining taxable profit (tax loss), tax bases, unused tax losses, unused tax credits and tax rates. That calculation should be based on which method provides better predictions of the resolution of the uncertainty.

IFRIC 23 is effective for annual reporting periods beginning on or after January 1, 2019. Earlier application is permitted. PEMEX does not anticipate being impacted by IFRIC 23 because all tax positions are discussed and agreed with the SHCP prior to releasing quarterly or annual financial statements.

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Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Disclosure of Consolidated Statements of Financial Position

Accordingly the balance as of these investments as of December 31, 2016 was reclassified for purposes of improving its presentation the consolidated statements of financial position as follows:

	2016
Line item	As previously (reported)		Reclassification			Following reclassification
Available—for—sale financial assets		Ps.          435,556		Ps. 2,417,123			Ps.       2,852,679
Total current assets		355,398,800		2,417,123			357,815,923
Investments in joint ventures and associates		23,154,632		(2,417,123	)		20,737,509
Total non-current assets		1,974,487,224		(2,417,123	)		1,972,070,101

Summary of Reclassification of Other Income (Expenses)

Due to the fact that reinsurance premiums from KOT Insurance Company, AG., from which PEMEX derives revenue, are not part of the core services provided by PEMEX, they are included in other income (expenses), net. Therefore, for comparison purposes, the consolidated statements of comprehensive income for the years ended December 31, 2016 and 2015 were reclassified as follow:

	2016
Line item	As previously (reported)		Reclassification			Following reclassification
Services income		Ps.     14,427,081		Ps. (5,452,439	)		Ps.       8,974,642
Total of sales		1,079,545,671		(5,452,439	)		1,074,093,232
Cost of sales		867,580,634		(1,758,413	)		865,822,221
Gross income (loss)		543,279,380		(3,694,026	)		539,585,354
Other income (expenses), net		18,955,580		3,694,026			22,649,606

	2015
Line item	As previously (reported)			Reclassification			Following reclassification
Services income		Ps.     12,912,112			Ps. (4,602,077	)		Ps.       8,310,035
Total of sales		1,166,362,469			(4,602,077	)		1,161,760,392
Cost of sales		895,068,904			(3,104,298	)		891,964,606
Gross income (loss)		(114,474,036	)		(1,497,779	)		(115,971,815	)
Other income (expenses), net		(2,373,266	)		1,497,779			(875,487	)

Summary of Better Presentation in Duties, Taxes and Other, Certain Amounts in Income Tax

In order to provide a better presentation in Duties, taxes and other, certain amounts in Income Tax line item, were reclassified to Hydrocarbon extraction duties and others line item, as follows:

	2016
Line item	As previously (reported)			Reclassification			Following reclassification
Hydrocarbon extraction duties and others		Ps.  304,813,375			Ps.  (27,651,571	)		Ps.  277,161,804
Income tax		(40,291,940	)		27,651,571			(12,640,369	)

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Segment financial information (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Condensed Financial Information of Segments after Elimination of Unrealized Intersegment Gain (Loss)

The following tables present the condensed financial information of these segments, after elimination of unrealized intersegment gain (loss), and include only select line items. As a result, the line items presented below may not total. These reporting segments are those which PEMEX’s management evaluates in its analysis of PEMEX and on which it bases its decision-making.

As of/for the year ended December 31, 2017	Exploration and Production			Industrial Transformation			Cogeneration and Services(1)			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies			Intersegment eliminations			Total
Sales:
Trade	Ps.	—			Ps. 857,456,146		Ps.	—		Ps.	—		Ps.	—			Ps. 4,123,006			Ps. 12,621,648			Ps. 508,539,112			Ps. 3,159,238		Ps.	—			Ps. 1,385,899,150
Intersegment		762,637,362			150,360,283			114,233			3,400,456			70,671,871			642,965			1,565,757			539,193,190			79,031,944			(1,607,618,061	)		—
Services income		—			6,116,937			334,755			41,741			3,714,941			2,339			26,733			66,621			826,502			—			11,130,569
(Reversal) impairment of wells pipelines, properties, plant and equipment, net		129,350,315			15,952,092			—			—			—			1,935,500			—			—			4,206,653			—			151,444,560
Cost of sales		391,089,410			1,004,683,554			472,732			468,171			50,926,263			6,001,259			14,272,340			1,031,997,901			33,033,923			(1,528,740,673	)		1,004,204,880
Gross income (loss)		242,197,637			(6,702,280	)		(23,744	)		2,974,026			23,460,549			(3,168,449	)		(58,202	)		15,801,022			45,777,108			(78,877,388	)		241,380,279
Other revenues (expenses), net		10,204,045			1,515,538			2,646			(31,454	)		(24,134,436	)		9,013			23,030			307,212			(5,344,872	)		22,623,354			5,174,076
Distribution, transportation and sales expenses		—			26,049,566			13,581			—			73,526			528,370			334,663			375,482			59,043			(5,544,561	)		21,889,670
Administrative expenses		58,539,119			38,994,887			37,679			888,776			7,459,928			352,537			1,105,554			1,564,859			62,001,641			(51,005,526	)		119,939,454
Operating income (loss)		193,862,563			(70,231,195	)		(72,358	)		2,053,796			(8,207,341	)		(4,040,343	)		(1,475,389	)		14,167,893			(21,628,448	)		296,053			104,725,231
Financing income		121,293,404			11,427,907			147			57,313			1,622,827			2,248			46,113			905,405			145,907,795			(265,097,306	)		16,165,853
Financing cost		(136,378,338	)		(2,398,643	)		(19,882	)		(795,947	)		(2,307,427	)		(211,004	)		(1,964	)		(1,328,827	)		(239,003,771	)		264,801,255			(117,644,548	)
Derivative financial instruments (cost) income, net		(1,613,874	)		5,835			—			—			—			—			—			(772,143	)		27,718,506			—			25,338,324
Foreign exchange (loss) income, net		10,043,316			4,924,209			—			227,365			613,099			(20,925	)		(10,486	)		(4,318	)		7,411,862			—			23,184,122
Profit (loss) sharing in joint ventures and associates		(75,195	)		485,224			—			—			(74	)		—			—			1,049,809			(212,666,494	)		211,567,170			360,440
Taxes, duties and other		338,169,260			—			—			276,967			(7,444,967	)		—			—			1,972,718			6,063			—			332,980,041
Net (loss) income		(151,037,384	)		(55,786,663	)		(92,093	)		1,265,560			(833,949	)		(4,270,024	)		(1,441,726	)		12,045,101			(292,266,613	)		211,567,172			(280,850,619	)
Total current assets		1,036,063,541			570,380,888			179,807			6,871,148			49,391,784			3,155,476			3,994,381			158,414,445			506,187,594			(1,971,112,774	)		363,526,290
Investments in joint ventures and associates		64,328			4			—			—			18,336			—			—			15,805,506			(465,026,224	)		465,845,414			16,707,364
Wells, pipelines, properties, plant and equipment, net		945,945,889			286,423,735			—			18,956,882			119,647,553			5,713,998			19,008,822			6,739,231			34,073,216			—			1,436,509,326
Total assets		2,058,036,405			857,196,306			179,807			26,220,748			191,895,993			8,923,456			23,142,045			186,808,899			2,111,740,735			(3,332,142,280	)		2,132,002,114
Total current liabilities		284,656,058			459,130,165			531,580			2,201,936			44,521,371			6,455,246			2,183,654			112,046,527			1,439,097,882			(1,961,697,234	)		389,127,185
Long-term debt		1,826,843,268			25,437,147			—			11,258,734			2,814,640			—			—			2,712,654			1,837,690,559			(1,826,091,398	)		1,880,665,604
Employee benefits		372,032,958			588,573,518			—			333,212			1,842,892			98,361			105,033			(966,238	)		296,416,386			—			1,258,436,122
Total liabilities		2,570,412,398			1,077,108,748			531,580			13,886,424			56,706,251			6,556,050			2,308,890			116,842,881			3,587,988,972			(3,797,987,695	)		3,634,354,499
Equity (deficit), net		(512,375,993	)		(219,912,442	)		(351,773	)		12,334,324			135,189,742			2,367,406			20,833,155			69,966,018			(1,476,248,237	)		465,845,415			(1,502,352,385	)
Depreciation and amortization		127,742,568			17,935,112			—			2,368,123			4,562,140			422,930			1,688,493			(19,798	)		2,004,945			—			156,704,513
Net periodic cost of employee benefits		32,794,386			52,538,989			—			39,697			(4,954	)		(1,999	)		(12,561	)		16,166			22,703,351			—			108,073,075
Acquisition of wells, pipelines, properties, plant and equipment		67,845,989			14,678,182			—			418,283			5,189,409			219,152			475,196			321,145			4,832,461			—			93,979,817

(1) Certain of the assets of Pemex Cogeneration and Services have been transferred to Pemex Industrial Transformation.

As of/for the year ended December 31, 2016	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies			Intersegment eliminations			Total
Sales:
Trade	Ps.	—		Ps.	648,088,013		Ps.	—		Ps.	—		Ps.	—		Ps.	3,873,403		Ps.	15,392,552		Ps.	395,118,117		Ps.	2,646,505		Ps.	—		Ps.	1,065,118,590
Intersegment		616,380,615			117,096,378			51,913			1,981,754			68,316,958			900,464			1,764,438			405,293,283			50,683,175			(1,262,468,978	)		—
Services income		—			5,565,604			132,521			70,112			2,813,887			1,908			60,141			236,230			473,415			(379,176	)		8,974,642
(Reversal) impairment of wells pipelines, properties, plant and equipment, net		(271,709,433	)		(52,498,881	)		—			—			(5,829,520	)		—			(1,276,509	)		—			—			—			(331,314,343	)
Cost of sales		359,064,884			823,763,927			166,721			143,956			61,248,584			5,506,198			13,936,213			783,691,245			7,260,043			(1,188,959,550	)		865,822,221
Gross income (loss)		529,025,164			(515,051	)		17,713			1,907,910			15,711,781			(730,423	)		4,557,427			16,956,385			46,543,052			(73,888,604	)		539,585,354
Other revenues (expenses), net		27,346,794			19,964,654			—			591,704			(27,189,969	)		32,710			63,989			3,412,711			(906,183	)		(666,804	)		22,649,606
Distribution, transportation and sales expenses		—			50,792,317			8,232			6			148,215			185,168			481,727			229,432			49,162			(26,663,019	)		25,231,240
Administrative expenses		54,509,047			34,183,846			32,126			983,560			7,175,451			731,479			2,101,834			1,157,182			60,497,232			(48,718,224	)		112,653,533
Operating income (loss)		501,862,911			(65,526,560	)		(22,645	)		1,516,048			(18,801,854	)		(1,614,360	)		2,037,855			18,982,482			(14,909,525	)		825,835			424,350,187
Financing income		56,040,129			11,056,345			—			72,995			373,301			4,358			64,582			1,098,079			125,964,466			(180,925,000	)		13,749,255
Financing cost		(109,946,363	)		(3,188,892	)		(12,055	)		(642,711	)		(481,741	)		(20,217	)		(2,980	)		(1,342,351	)		(163,400,779	)		180,193,625			(98,844,464	)
Derivative financial instruments (cost) income, net		—			3,172			—			—			—			—			—			(1,951,959	)		(12,052,200	)		—			(14,000,987	)
Foreign exchange (loss) income, net		(217,166,718	)		(12,858,875	)		—			(1,570,317	)		(1,118,537	)		(29,263	)		(2,843	)		174,866			(21,441,056	)		—			(254,012,743	)
Profit (loss) sharing in joint ventures and associates		(21,164	)		649,520			—			—			—			—			—			1,586,503			(117,426,818	)		117,347,804			2,135,845
Taxes, duties and other		276,647,448			—			—			(481,581	)		(10,010,686	)		—			—			7,380,870			(9,014,616	)		—			264,521,435
Net (loss) income		(45,878,653	)		(69,865,290	)		(34,700	)		(142,404	)		(10,018,145	)		(1,659,482	)		2,096,614			11,166,750			(194,251,296	)		117,442,264			(191,144,342	)
Total current assets		983,260,710			795,237,287			388,422			6,032,213			22,087,801			1,724,967			5,817,262			125,081,531			613,881,578			(2,195,695,848	)		357,815,923
Investments in joint ventures and associates		139,523			257,159			—			—			—			—			—			17,568,893			(247,349,711	)		250,121,645			20,737,509
Wells, pipelines, properties, plant and equipment, net		1,176,504,263			311,432,174			—			21,023,629			86,695,514			7,771,634			20,086,650			6,691,813			37,536,571			—			1,667,742,248
Total assets		2,206,418,541			1,107,094,580			388,423			27,673,598			130,824,921			9,556,469			26,007,319			155,376,864			2,359,024,145			(3,692,478,836	)		2,329,886,024
Total current liabilities		340,011,451			666,467,674			472,236			3,894,121			19,824,792			2,995,088			3,879,828			78,894,485			1,497,612,971			(2,187,862,760	)		426,189,886
Long-term debt		1,737,109,328			31,495,027			—			12,489,423			4,382,109			—			—			3,597,938			1,757,315,685			(1,739,384,968	)		1,807,004,542
Employee benefits		362,312,386			575,277,374			191,876			441,127			571,702			20,362			21,893			(749,034	)		282,321,750			—			1,220,409,436
Total liabilities		2,533,221,665			1,278,138,290			664,829			16,853,202			29,336,417			3,015,450			3,901,722			86,885,889			3,553,477,189			(3,942,600,482	)		3,562,894,171
Equity (deficit), net		(326,803,124	)		(171,043,710	)		(276,406	)		10,820,396			101,488,504			6,541,019			22,105,597			68,490,975			(1,194,453,044	)		250,121,646			(1,233,008,147	)
Depreciation and amortization		124,329,921			17,425,472			—			2,559,357			2,230,557			481,241			1,395,232			86,707			1,931,004			—			150,439,491
Net periodic cost of employee benefits		32,617,215			52,886,397			5,860			31,491			30,340			(1,178	)		1,424			(552,735	)		24,719,602			—			109,738,416
Acquisition of wells, pipelines, properties, plant and equipment		70,418,370			32,254,531			—			2,053,139			26,344,495			889,420			1,724,690			1,019,484			21,031,214			—			155,735,343

As of/for the year ended December 31, 2015	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies			Intersegment eliminations			Total
Sales:
Trade	Ps.	—		Ps.	740,190,020		Ps.	—		Ps.	—		Ps.	—		Ps.	1,494,478		Ps.	4,551,413		Ps.	407,214,446		Ps.	—		Ps.	—		Ps.	1,153,450,357
Intersegment		690,642,133			126,294,195			—			1,511,970			598,853			209,970			473,990			353,137,149			18,296,515			(1,191,164,775	)		—
Services income		—			7,549,061			—			—			10,355,988			236			17,893			661,683			505,032			(10,779,858	)		8,310,035
Impairment of wells, pipelines, properties, plant and equipment		394,396,580			76,442,079			—			—			5,829,519			—			1,276,512			—			—			—			477,944,690
Benefit from change in pension plan		(46,368,308	)		(45,808,781	)		—			—			—			—			—			—			—			—			(92,177,089	)
Cost of sales		427,158,621			876,531,944			2,793			706,896			10,727,462			1,707,548			4,965,414			749,655,199			2,791,350			(1,182,282,621	)		891,964,606
Gross income (loss)		(84,544,760	)		(33,131,966	)		(2,793	)		805,074			(5,602,140	)		(2,864	)		(1,198,630	)		11,358,079			16,010,197			(19,662,012	)		(115,971,815	)
Other revenues (expenses), net		(7,957,202	)		1,243,040			—			38			26,941			14,680			19,909			1,666,783			2,219,539			1,890,785			(875,487	)
Distribution, transportation and sales expenses		—			35,292,527			1,448			—			3,009			4,416			62,071			428,613			254			(6,863,699	)		28,928,639
Administrative expenses		18,454,281			40,529,587			47,670			8,553			104,794			152,404			519,351			1,967,581			61,609,813			(10,921,939	)		112,472,095
Benefit from change in pension plan		(17,853,725	)		(39,975,450	)		—			—			—			—			—			—			(46,031,780	)		—			(103,860,955	)
Operating income (loss)		(93,102,518	)		(67,735,590	)		(51,911	)		796,559			(5,683,002	)		(145,004	)		(1,760,143	)		10,628,668			2,651,449			14,411			(154,387,081	)
Financing income		25,852,078			2,789,535			—			43,690			37			3,503			7,728			1,147,870			110,816,691			(125,670,273	)		14,990,859
Financing cost		(90,822,360	)		(13,738,104	)		2,110			(95,280	)		(61,153	)		—			—			(1,299,580	)		(87,289,616	)		125,530,390			(67,773,593	)
Derivative financial instruments (cost) income, net		—			6,463			—			—			—			—			—			1,347,323			(22,803,663	)		—			(21,449,877	)
Foreign exchange (loss), net		(132,165,427	)		(7,364,486	)		(7,509	)		(92,046	)		(11,090	)		(3,600	)		(2,802	)		(49,190	)		(15,069,424	)		—			(154,765,574	)
(Loss) profit sharing in joint ventures and associates		(473,082	)		671,868			—			—			—			—			—			2,056,259			(749,900,890	)		749,963,960			2,318,115
Taxes, duties and other		376,682,705			1,839,021			—			197,491			(2,069,848	)		—			—			5,134,176			(50,283,298	)		—			331,500,247
Net (loss) income		(667,394,014	)		(87,209,335	)		(57,310	)		455,432			(3,685,360	)		(145,101	)		(1,755,217	)		8,697,174			(711,312,155	)		749,838,488			(712,567,398	)
Total current assets		709,252,019			313,801,630			655,239			2,171,717			49,162,929			1,594,643			4,988,511			73,116,155			275,582,816			(1,163,125,162	)		267,200,497
Investments in joint ventures and associates		919,654			6,687,977			—			—			—			8,500			—			11,845,489			(242,233,405	)		246,937,384			24,165,599
Wells, pipelines, properties, plant and equipment, net		966,144,619			246,463,069			—			22,647,454			58,078,603			7,405,969			18,480,684			3,045,704			22,217,529			—			1,344,483,631
Total assets		1,698,909,240			567,486,579			655,240			24,917,981			111,307,038			9,034,376			23,705,118			93,266,620			1,443,189,885			(2,196,817,877	)		1,775,654,200
Total current liabilities		278,507,394			104,569,842			469,524			1,981,652			14,698,159			1,486,468			4,534,980			34,749,438			1,157,183,570			(1,154,773,306	)		443,407,721
Long-term debt		1,252,239,594			16,707,005			—			12,031,849			4,850,905			—			—			3,607,840			1,285,676,066			(1,274,240,092	)		1,300,873,167
Employee benefits		379,150,943			609,492,623			61,171			417,817			368,036			12,533			3,611			(59,581	)		289,938,288			—			1,279,385,441
Total liabilities		1,985,557,185			735,280,560			530,696			14,431,318			19,917,100			1,499,001			4,538,591			41,420,792			2,747,910,113			(2,443,755,258	)		3,107,330,098
Equity (deficit), net		(286,647,945	)		(167,793,981	)		124,544			10,486,663			91,389,938			7,535,375			19,166,527			51,845,828			(1,304,720,228	)		246,937,381			(1,331,675,898	)
Depreciation and amortization		144,567,149			20,916,796			—			612,741			337,364			158,505			442,504			84,493			831,698			—			167,951,250
Net periodic cost of employee benefits		23,608,485			21,392,600			(298	)		—			(310	)		—			—			(119,819	)		17,668,484			—			62,549,142
Acquisition of wells, pipelines, properties, plant and equipment		184,786,051			68,935,841			—			—			1,544,224			320,762			1,882,108			677,314			6,711,511			—			264,857,811

Schedule of Accounting Reconciliations Between Individual and Consolidated Information

The following tables present accounting reconciliations between individual and consolidated information.

As of/for the year ended December 31, 2017	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies
Sales:
By segment		Ps.   762,637,362			1,015,157,118			448,988			6,679,132			74,386,812			4,795,196			14,214,138			1,047,874,453			83,017,684
Less unrealized intersegment sales		—			(1,223,752	)		—			(3,236,935	)		—			(26,886	)		—			(75,530	)		—
Total consolidated sales		Ps.   762,637,362			1,013,933,366			448,988			3,442,197			74,386,812			4,768,310			14,214,138			1,047,798,923			83,017,684
Operating income (loss):
By segment		Ps.   194,814,292			(59,989,652	)		(72,358	)		882,692			(61,696,313	)		(7,148,431	)		(4,698,838	)		14,490,017			(21,628,448	)
Less unrealized intersegment sales		—			(1,223,752	)		—			(3,236,935	)		—			(26,886	)		—			(75,530	)		—
Less unrealized gain due to production cost valuation of inventory		(496,329	)		(9,017,791	)		—			2,932,663			—			—			—			(246,594	)		—
Less capitalized refined products		(574,381	)		—			—			—			—			—			—			—			—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			—			—
Less depreciation and impairment of revaluated transferred assets		—			—			—			1,475,376			53,488,972			3,134,974			3,223,449			—			—
Total consolidated operating income (loss)		Ps.   193,862,563			(70,231,195	)		(72,358	)		2,053,796			(8,207,341	)		(4,040,343	)		(1,475,389	)		14,167,893			(21,628,448	)
Net income (loss):
By segment		Ps. (150,388,699	)		(44,599,751	)		(358,862	)		345,913			(40,300,942	)		(8,616,130	)		(5,866,542	)		5,200,268			(292,266,613	)
Less unrealized intersegment sales		—			(1,223,752	)		—			(3,236,935	)		—			(26,886	)		—			(75,530	)		—
Less unrealized gain due to production cost valuation of inventory		(496,329	)		(9,017,791	)		—			2,932,663			—			—			—			(246,594	)		—
Less capitalized refined products		(574,381	)		—			—			—			—			—			—			—			—
Less equity method elimination		303,044			(945,369	)		266,769			—			333			1,238,018			1,201,367			7,166,957			—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			—			—
Less depreciation and impairment of revaluated transferred assets, net of deferred taxes		—			—			—			1,223,919			39,466,660			3,134,974			3,223,449			—			—
Total consolidated net (loss) income		Ps. (151,037,384	)		(55,786,663	)		(92,093	)		1,265,560			(833,949	)		(4,270,024	)		(1,441,726	)		12,045,101			(292,266,613	)
Assets:
By segment		Ps. 2,084,553,745			912,770,881			179,807			28,256,876			276,537,764			17,689,305			35,498,783			195,538,239			2,111,740,735
Less unrealized intersegment sales		858,094			(5,389,977	)		—			—			7,183			—			(5,303	)		(408,059	)		—
Less unrealized gain due to production cost valuation of inventory		(3,657,242	)		(42,379,229	)		—			—			—			(26,886	)		—			(7,163,664	)		—
Less capitalized refined products		(574,381	)		—			—			—			—			—			—			—			—
Less depreciation and impairment of revaluated transferred assets, net of deferred taxes		(22,503,168	)		—			—			(2,036,128	)		(84,557,831	)		(2,165,068	)		(9,522,686	)		(424,849	)		—
Less equity method for unrealized profits		(759,624	)		(7,813,492	)		—			—			(91,123	)		(6,573,895	)		(2,828,749	)		(732,768	)		—
Less amortization of capitalized interest		118,981			8,123			—			—			—			—			—			—			—
Total consolidated assets		Ps. 2,058,036,405			857,196,306			179,807			26,220,748			191,895,993			8,923,456			23,142,045			186,808,899			2,111,740,735
Liabilities:
By segment		Ps. 2,570,412,398			1,081,528,677			531,580			13,186,297			56,706,251			6,556,050			2,308,890			116,648,398			3,587,988,972
Less unrealized intersegment sales		—			(4,419,929	)		—			700,127			—			—			—			194,483			—
Total consolidated liabilities		Ps. 2,570,412,398			1,077,108,748			531,580			13,886,424			56,706,251			6,556,050			2,308,890			116,842,881			3,587,988,972

As of/for the year ended December 31, 2016	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services			Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies
Sales:
By segment		Ps. 616,380,615			771,597,427			184,434			6,263,093			71,130,845			4,775,775			17,217,131			800,979,076			53,803,095
Less unrealized intersegment sales		—			(847,432	)		—			(4,211,227	)		—			—			—			(331,446	)		—
Total consolidated sales		Ps. 616,380,615			770,749,995			184,434			2,051,866			71,130,845			4,775,775			17,217,131			800,647,630			53,803,095
Operating income (loss):
By segment		Ps. 503,679,153			(60,347,367	)		(22,645	)		1,271,202			(25,701,065	)		(2,877,725	)		(3,504,812	)		19,526,997			(14,909,525	)
Less unrealized intersegment sales		—			(847,432	)		—			(4,211,227	)		—			—			—			(331,446	)		—
Less unrealized gain due to production cost valuation of inventory		(273,237	)		3,572,498			—			3,815,371			—			905,910			(2,163	)		(213,069	)		—
Less capitalized refined products		(1,661,986	)		(7,904,259	)		—			—			—			—			—			—			—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			—			—
Less depreciation and impairment of revaluated assets		—			—			—			640,702			6,899,211			357,455			5,544,830			—			—
Total consolidated operating income (loss)		Ps. 501,862,911			(65,526,560	)		(22,645	)		1,516,048			(18,801,854	)		(1,614,360	)		2,037,855			18,982,482			(14,909,525	)
Net income (loss):
By segment		Ps. (44,069,001	)		(61,639,067	)		(381,214	)		(387,250	)		(16,917,356	)		(7,820,835	)		(3,780,706	)		11,711,265			(194,251,296	)
Less unrealized intersegment sales		—			(847,432	)		—			(4,211,227	)		—			—			—			(331,446	)		—
Less unrealized gain due to production cost valuation of inventory		(273,237	)		3,572,498			—			3,815,371			—			905,910			(2,163	)		(213,069	)		—
Less capitalized refined products		(1,661,986	)		(7,904,259	)		—			—			—			—			—			—			—
Less equity method elimination		6,590			(3,047,030	)		346,514			—			—			4,897,988			334,653			—			—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			—			—
Less depreciation of revaluated assets		—			—			—			640,702			6,899,211			357,455			5,544,830			—			—
Total consolidated net (loss) income		Ps. (45,878,653)			(69,865,290	)		(34,700	)		(142,404	)		(10,018,145	)		(1,659,482	)		2,096,614			11,166,750			(194,251,296	)
Assets: By segment		Ps.2,232,052,453			1,151,907,566			425,141			30,990,147			254,615,026			10,421,225			43,067,636			170,782,928			2,359,024,145
Less unrealized intersegment sales		483,230			(4,158,101	)		—			—			—			—			(5,304	)		(332,529	)		—
Less unrealized gain due to production cost valuation of inventory		(3,246,782	)		(33,361,438	)		—			—			—			—			—			(5,688,341	)		—
Less capitalized refined products		(1,661,986	)		—			—			—			—			—			—			—			—
Less depreciation of revalued assets		(20,585,300	)		—			—			(3,316,549	)		(123,790,105	)		(5,300,044	)		(12,746,136	)		(652	)		—
Less equity method for unrealized profits		(742,055	)		(7,293,447	)		(36,718	)		—			—			4,435,288			(4,308,877	)		(8,960,344	)		—
Less amortization of capitalized interest		118,981			—			—			—			—			—			—			(424,198	)		—
Total consolidated assets		Ps.2,206,418,541			1,107,094,580			388,423			27,673,598			130,824,921			9,556,469			26,007,319			155,376,864			2,359,024,145
Liabilities:
By segment		Ps.2,533,221,665			1,282,558,220			664,829			16,457,347			29,336,417			3,015,450			3,901,722			85,392,123			3,553,477,189
Less unrealized intersegment sales		—			(4,419,930	)		—			395,855			—			—			—			1,493,766			—
Total consolidated liabilities		Ps.2,533,221,665			1,278,138,290			664,829			16,853,202			29,336,417			3,015,450			3,901,722			86,885,889			3,553,477,189

As of/for the year ended December 31, 2015	Exploration and Production			Industrial Transformation			Cogeneration and Services			Drilling and Services		Logistics			Fertilizers			Ethylene			Trading Companies			Corporate and Other Operating Subsidiary Companies
Sales:
By segment	Ps.	690,642,133			874,630,488			—			1,511,970		10,954,841			1,704,684			5,048,600			761,213,475			18,801,547
Less unrealized intersegment sales		—			(597,212	)		—			—		—			—			(5,304	)		(200,197	)		—
Total consolidated sales	Ps.	690,642,133			874,033,276			—			1,511,970		10,954,841			1,704,684			5,043,296			761,013,278			18,801,547
Operating income (loss):
By segment	Ps.	(89,473,302	)		(88,819,558	)		(51,911	)		700,748		(6,875,252	)		(262,145	)		(2,288,747	)		10,334,138			2,651,449
Less unrealized intersegment sales		—			(597,212	)		—			—		—			—			(5,304	)		(200,197	)		—
Less unrealized gain due to production cost valuation of inventory		(251,995	)		21,681,180			—			—		—			—			2,163			494,727			—
Less capitalized refined products		(3,496,201	)		—			—			—		—			—			—			—			—
Less amortization of capitalized interest		118,980			—			—			—		—			—			—			—			—
Less depreciation and impairment of revaluated assets		—			—			—			95,811		1,192,250			117,141			531,745			—			—
Total consolidated operating (loss) income	Ps.	(93,102,518	)		(67,735,590	)		(51,911	)		796,559		(5,683,002	)		(145,004	)		(1,760,143	)		10,628,668			2,651,449
Net income (loss):
By segment	Ps.	(663,719,119	)		(107,164,261	)		(57,310	)		359,621		(4,877,610	)		(262,242	)		(2,314,774	)		8,402,644			(711,312,155	)
Less unrealized intersegment sales		—			(597,212	)		—			—		—			—			(5,304	)		(200,197	)		—
Less unrealized gain due to production cost valuation of inventory		(251,995	)		21,681,180			—			—		—			—			2,163			494,727			—
Less capitalized refined products		(3,496,201	)		—			—			—		—			—			—			—
Less equity method elimination		(45,679	)		(1,129,042	)		—			—		—			—			30,953			—			—
Less amortization of capitalized interest		118,980			—			—			—		—			—			—			—			—
Less depreciation of revaluated assets		—			—			—			95,811		1,192,250			117,141			531,745			—			—
Total consolidated net (loss) income	Ps.	(667,394,014	)		(87,209,335	)		(57,310	)		455,432		(3,685,360	)		(145,101	)		(1,755,217	)		8,697,174			(711,312,155	)

Supplemental Geographic Information

Supplemental geographic information:

	For the years ended December 31,
	2017		2016		2015
Domestic sales	Ps.	877,360,038	Ps.	670,000,473	Ps.	746,235,912
Export sales:
United States		302,912,999		221,954,461		266,826,499
Canada, Central and South America		13,943,080		14,058,897		11,027,813
Europe		71,470,613		64,348,997		58,707,787
Other		120,212,420		94,755,762		70,652,346
Total export sales		508,539,112		395,118,117		407,214,445
Services income		11,130,569		8,974,642		8,310,035
Total sales	Ps.	1,397,029,719	Ps.	1,074,093,232	Ps.	1,161,760,392

Schedule of Income By Product

The following table shows income by product:

	For the years ended December 31,
	2017		2016		2015
Domestic sales
Refined petroleum products and derivatives (primarily gasolines)		Ps. 784,048,048		Ps. 578,718,674		Ps. 660,573,780
Gas		70,930,855		59,648,576		54,497,824
Petrochemical products		22,381,135		31,633,223		31,164,308
Total domestic sales		Ps. 877,360,038		Ps. 670,000,473		Ps. 746,235,912
Export sales
Crude oil		Ps. 380,461,147		Ps. 288,625,794		Ps. 288,170,451
Refined petroleum products and derivatives (primarily gasolines)		109,615,457		92,705,248		118,129,615
Gas		21,675		20,995		27,283
Petrochemical products		18,440,833		13,766,080		887,096
Total export sales		Ps. 508,539,112		Ps. 395,118,117		Ps. 407,214,445

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Cash, Cash Equivalents and Restricted Cash (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Summary of Cash and Cash Equivalents

a. As of December 31, 2017 and 2016, cash and cash equivalents were as follows:

	2017		2016
Cash on hand and in banks(i)	Ps.	55,871,127	Ps.	71,430,427
Highly liquid investments(ii)		41,980,627		92,102,086
	Ps.	97,851,754	Ps.	163,532,513

(i) Cash on hand and in banks is primarily composed of cash in banks.

(ii) Mainly composed of short-term Mexican Government investments.

b. At December 31, 2017 and 2016, restricted cash was as follows:

	2017		2016
Restricted cash		Ps.               —	Ps.	10,478,626

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Accounts Receivable, Net (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Summary of Accounts Receivable and Other Receivables

As of December 31, 2017 and 2016, accounts receivable and other receivables were as follows:

	2017		2016
Domestic customers, net	Ps.	60,057,141	Ps.	41,884,579
Export customers, net		54,428,883		34,859,341
Sundry debtors		26,105,703		18,736,922
Taxes to be recovered and prepaid taxes		23,039,023		29,361,303
Employees and officers		5,681,478		6,054,251
Advances to suppliers		1,250,846		2,246,437
Other accounts receivable		82,160		77,694
	Ps.	170,645,234	Ps.	133,220,527

Schedule of Breakdown of Accounts Receivable Based on Credit History

The following table shows a breakdown of accounts receivable based on their credit history at December 31, 2017 and 2016:

	Domestic customers
	2017			2016
1 to 30 days	Ps.	10,188,070			Ps.1,767,718
31 to 60 days		4,081,862			658,456
61 to 90 days		777,409			263,447
More than 90 days(i)		11,345,933			1,016,553
Past due		26,393,274			3,706,174
Impaired (reserved)		(951,932	)		(458,428	)
Unimpaired		25,441,342			3,247,746
Current		34,615,799			38,636,833
Total	Ps.	60,057,141			Ps.41,884,579

⁽ⁱ⁾ The increase in 2017 in accounts receivable invoices more than 90 days old is primarily due to the termination of the outstanding balances compensation system in place between Mexican Government owned companies.

	Export customers
	2017			2016
1 to 30 days	Ps.	334,155		Ps.	341,184
31 to 60 days		—			6,824
61 to 90 days		—			35,372
More than 90 days		315,888			624,157
Past due		650,043			1,007,537
Impaired (reserved)		(272,813	)		(374,699	)
Unimpaired		377,230			632,838
Current		54,051,653			34,226,503
Total	Ps.	54,428,883		Ps.	34,859,341

Summary of Reconciliation for Impaired Accounts Receivable

Additionally, the reconciliation for impaired accounts receivable is as follows:

	Domestic customers
	2017			2016
Balance at the beginning of the year		Ps. (458,428	)		Ps. (667,883	)
Additions against income		(493,514	)		(218,836	)
Amount used		10			428,291
Balance at the end of the year		Ps. (951,932	)		Ps. (458,428	)
	Export customers
	2017			2016
Balance at the beginning of the year		Ps. (374,699	)		Ps. (312,004	)
Additions against income		(204,713	)		(25,931	)
Amount used		297,047			—
Translation effects		9,552			(36,764	)
Balance at the end of the year		Ps. (272,813)			Ps. (374,699)

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Inventories, Net (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Summary of Inventories

As of December 31, 2017 and 2016, inventories were as follows:

	2017		2016
Refined and petrochemicals products		Ps. 27,862,384		Ps. 21,534,846
Products in transit		19,112,606		7,735,163
Crude oil		11,445,780		11,391,310
Materials and products in stock		5,172,779		4,721,834
Materials in transit		180,711		419,547
Gas and condensate products		84,670		89,360
		Ps. 63,858,930		Ps. 45,892,060

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Investments in Joint Ventures and Associates (Tables)

12 Months Ended

Dec. 31, 2017

Investments Schedule [Abstract]

Schedule of Permanent Investments in joint Ventures and Associates

The investments in joint ventures and associates as of December 31, 2017 and 2016, were as follows:

		Percentage of investment		December 31,
				2017		2016
Deer Park Refining Limited			49.99%		Ps.14,405,542		Ps.14,039,384
Petroquímica Mexicana de Vinilo, S. A. de C. V.	(i)		44.09%		—		4,309,050
Sierrita Gas Pipeline LLC			35.00%		1,084,169		1,112,338
Frontera Brownsville, LLC.			50.00%		471,085		478,414
CH4 Energía, S. A.			50.00%		315,713		194,868
Texas Frontera, LLC.			50.00%		239,782		260,828
Administración Portuaria Integral de Dos Bocas, S.A. de C.V.			40.00%		64,328		139,523
PMV Minera, S.A. de C.V.			44.09%		45,133		61,779
Ductos el peninsular, S.A.P.I de C. V.			50.00%		18,336		18,626
Other-net			Various		63,276		122,699
					Ps.16,707,364		Ps.20,737,509

i. On April 20, 2016, an explosion occurred in the “Planta de Clorados 3” (Chlorinated Plant 3) of the Petroquímica Mexicana de Vinilo, resulting in approximately U.S. $ 461,000 in damages. Chorinated Plant 3 incurred the greatest amount of damage, including the loss of certain assets and the closure of the plant for an undefined amount of time. The Chlorine-Soda plants and the ethylene plants did not register any damage. On December 20, 2017, Petroquímica Mexicana de Vinilo permanently closed the plant, and -the full book value was written-off impacting the value of this investment.

Schedule Profit Sharing in Joint Ventures and Associates

Profit (loss) sharing in joint ventures and associates:

	2017			2016			2015
Deer Park Refining Limited		Ps. 920,409			Ps. 1,437,850			Ps. 1,913,835
Ductos y Energéticos del Norte, S.A. de C.V.(i)		360,092			—			—
CH4 Energía S.A. de C.V.		125,132			—			—
Sierrita Gas Pipeline LLC		129,401			105,825			152,445
PMV Minera, S.A. de C.V.		6,253			—			—
Petroquímica Mexicana de Vinilo, S. A. de C. V.		(1,223,640	)		(190,468	)		(61,952	)
Administración Portuaria Integral de Dos Bocas, S.A. de C.V.		(75,195	)		—			—
Gasoductos de Chihuahua, S. de R. L. de C. V.(ii)		—			638,126			666,779
Compañía Mexicana de Exploraciones, S. A. de C. V.(iii)		—			—			(496,774	)
Other, net		117,988			144,512			143,782
Profit sharing in joint ventures and associates, net		Ps. 360,440			Ps. 2,135,845			Ps. 2,318,115

i. In November 2017, PEMEX sold its 50% interest in Ductos y Energéticos del Norte, S. de R.L. de C. V., to Infraestructura Energética Nova, S.A.B. of C.V. for a total of U.S. $ 3,141,710, yielding a profit of Ps. 3,139,103.

ii. On September 28, 2016, PEMEX completed the divestiture of its 50% ownership interest in the Gasoductos de Chihuahua S. de R.L. de C.V. joint venture with Infraestructura Energética Nova, S.A.B. de C.V. The stock was sold for Ps. 22,684,736, yielding a profit of Ps. 15,211,039.

iii. Beginning July 1, 2016 this company was included in the consolidated financial statements of PEMEX. Until June 30, 2016 this Company was accounted for as an investment in an associate under the equity method (see Note 3-a).

Schedule of Condensed Financial Information of Major Investments Recognized Under the Equity Method

The following tables show condensed financial information of major investments recognized under the equity method during 2017 and 2016:

Condensed statements of financial position
	Deer Park Refining Limited				Sierrita Gas Pipeline, LLC
	2017		2016		2017		2016
Total assets		Ps. 41,075,547		Ps. 42,428,275		Ps.3,518,036		Ps.3,244,811
Total liabilities		Ps. 12,261,581		Ps. 14,346,643		Ps.   420,410		Ps.     66,703
Total equity		28,813,966		28,081,632		3,097,626		3,178,108
Total liabilities and equity		Ps.41,075,547		Ps. 42,428,275		Ps.3,518,036		Ps.3,244,811

Condensed statements of comprehensive income

Deer Park Refining Limited

Sierrita Gas Pipeline, LLC

Gasoductos de Chihuahua, S. de R. L. de C. V.

December 31,

December 31,

August 31,

December 31,

2017

2016

2015

2017

2016

2016

2015

Sales and other income

Ps.16,427,064

Ps.16,750,155

Ps.16,658,705

Ps. 840,414

Ps. 717,351

Ps.3,798,666

Ps.4,617,982

Costs and expenses

14,586,061

13,874,172

12,830,653

470,697

414,994

2,522,415

3,284,424

Net result

Ps. 1,841,003

Ps. 2,875,983

Ps. 3,828,052

Ps. 369,717

Ps. 302,357

Ps.1,276,251

Ps.1,333,558

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Wells, Pipelines, Properties, Plant and Equipment, Net (Tables)

12 Months Ended

Dec. 31, 2017

Detailed Information About Property, Plant and Equipment

	Plants			Drilling equipment			Pipelines			Wells			Buildings			Offshore platforms			Furniture and equipment			Transportation equipment			Construction in progress			Land			Unproductive fixed assets			Other fixed assets			Total fixed assets
Investment
Balances as of January 1, 2016		Ps. 648,412,014			21,680,343			419,979,508			1,066,515,651			66,284,466			260,328,096			52,966,194			15,329,095			211,675,597			43,347,802			—			630,878			2,807,149,644
Acquisitions		20,406,464			1,629,710			1,265,011			8,239,480			2,541,802			9,866,984			545,271			2,063,519			107,682,868			1,487,434			6,800			—			155,735,343
Reclassifications		150,817			—			(1,268,887	)		8,649,686			(6,610,184	)		—			(561,569	)		(325,778	)		(282,044	)		50,709			2,039			(137,246	)		(332,457	)
Capitalization		15,943,630			—			11,851,378			40,825,973			1,085,323			17,318,279			2,769			2,918,621			(89,945,973	)		—			—			—			—
Impairment		81,135,967			—			31,967,407			198,974,994			—			35,640,491			438,979			8,743			(16,852,238	)		—			—			—			331,314,343
Disposals		(7,602,782	)		(40,937	)		(3,648,989	)		(4,382,867	)		(558,374	)		(449,645	)		(2,644,957	)		(551,355	)		(4,864,062	)		(314,327	)		(8,839	)		(2,126	)		(25,069,260	)
Balances as of December 31, 2016		758,446,110			23,269,116			460,145,428			1,318,822,917			62,743,033			322,704,205			50,746,687			19,442,845			207,414,148			44,571,618			—			491,506			3,268,797,613
Acquisitions		10,018,030			418,283			7,054,793			14,937,882			802,300			7,811,374			1,183,679			284,445			51,410,469			58,563			—			—			93,979,818
Reclassifications		3,146,955			—			(53,349	)		—			98,245			(10,199,213	)		(96,899	)		(75,674	)		(812,943	)		(560	)		—			4,072,464			(3,920,974	)
Capitalization		43,033,864			—			21,357,074			36,564,811			1,265,246			8,677,765			30,879			3,746,395			(114,700,828	)		29,248			—			(4,454	)		—
Impairment		(48,020,616	)		—			2,226,771			(83,236,991	)		—			(15,564,190	)		—			—			(6,849,534	)		—			—			—			(151,444,560	)
Disposals		(10,598,983	)		(244,283	)		(8,862,541	)		(19,340,709	)		(208,353	)		—			(806,694	)		(226,375	)		(6,724,930	)		(112,170	)		—			(4,440,865	)		(51,565,902	)
Balances as of December 31, 2017		Ps. 756,025,360			23,443,116			481,868,176			1,267,747,910			64,700,471			313,429,941			51,057,652			23,171,636			129,736,382			44,546,699			—			118,651			3,155,845,995
Accumulated depreciation and amortization
Balances as of January 1, 2016		Ps.(321,283,906	)		(578,015	)		(139,331,407	)		(780,443,639	)		(37,712,087	)		(140,908,960	)		(36,513,479	)		(5,894,520	)		—			—			—			—			(1,462,666,013	)
Depreciation and amortization		(44,549,443	)		(2,364,560	)		(15,153,879	)		(70,090,038	)		(1,796,383	)		(12,252,810	)		(3,205,089	)		(1,027,289	)		—			—			—			—			(150,439,491	)
Reclassifications		(10,521	)		—			(166,632	)		(3,077	)		(108,718	)		—			166,914			454,492			—			—			—			—			332,458
Disposals		5,826,891			—			2,286,691			—			492,557			—			2,560,988			550,554			—			—			—			—			11,717,681
Balances as of December 31, 2016		(360,016,979	)		(2,942,575	)		(152,365,227	)		(850,536,754	)		(39,124,631	)		(153,161,770	)		(36,990,666	)		(5,916,763	)		—			—			—			—			(1,601,055,365	)
Depreciation and amortization		(45,709,123	)		(2,198,867	)		(15,095,115	)		(74,673,473	)		(1,906,164	)		(13,192,369	)		(2,890,563	)		(1,038,839	)		—			—			—			—			(156,704,513	)
Reclassifications		2,799,244			—			(72,841	)		—			(69,236	)		1,146,904			102,375			14,532			—			—			—			—			3,920,978
Disposals		8,902,711			127,458			7,573,769			16,810,591			59,022			—			805,916			222,764			—			—			—			—			34,502,231
Balances as of December 31, 2017		Ps.(394,024,147	)		(5,013,984	)		(159,959,414	)		(908,399,636	)		(41,041,009	)		(165,207,235	)		(38,972,938	)		(6,718,306	)		—			—			—			—			(1,719,336,669	)
Wells, pipelines, properties, plant and equipment—net as of December 31, 2016		Ps. 398,429,131			20,326,541			307,780,201			468,286,163			23,618,402			169,542,435			13,756,021			13,526,082			207,414,148			44,571,618			—			491,506			1,667,742,248
Wells, pipelines, properties, plant and equipment—net as of December 31, 2017		Ps. 362,001,214			18,429,132			321,908,762			359,348,274			23,659,462			148,222,706			12,084,714			16,453,330			129,736,382			44,546,699			—			118,651			1,436,509,326
Depreciation rates		3 to 5	%		5	%		2 to 7	%		—			3 to 7	%		4	%		3 to 10	%		4 to 20	%		—			—			—			—			—
Estimated useful lives		20 to 35			20			15 to 45			—			33 to 35			25			3 to 10			5 to 25			—			—			—			—			—

a. As of December 31, 2017, 2016 and 2015, the financing cost identified with fixed assets in the construction or installation stage, capitalized as part of the value of such fixed assets, was Ps. 3,060,963, Ps. 3,667,752 and Ps. 5,258,854, respectively.

b. The combined depreciation of fixed assets and amortization of wells for the fiscal years ended December 31, 2017, 2016 and 2015, recognized in operating costs and expenses, was Ps.156,704,513, Ps. 150,439,491 and Ps. 167,951,250, respectively, which includes costs related to plugging and abandonment of wells for the years ended December 31, 2017, 2016 and 2015 of Ps. 850,015, Ps. 1,698,312, and Ps. 1,401,870, respectively.

c. As of December 31, 2017 and 2016, provisions relating to future plugging of wells costs amounted to Ps. 68,797,600 and Ps. 64,967,710, respectively, and are presented in the “Provisions for plugging of wells” (see Note 18).

d. As of December 31, 2017 and 2016, acquisitions of property, plant and equipment include transfers from wells unassigned to a reserve for Ps. 16,440,645 and Ps. 16,393,773, respectively (see Note 13) and Ps. 4,652,314 from available-for-sale non-financial assets as of December 31, 2017 (see Note 9).

e. As of December 31, 2017 and 2016, PEMEX recognized a net impairment of Ps. 151,444,560 and a net reversal of impairment of Ps. 331,314,343, respectively, which is presented as a separate line item in the consolidated statement of comprehensive income as follows:

Assets Acquired Through Capital Leases

As of December 31, 2017 and 2016, assets acquired through these capital leases were as follows:

	2017			2016
Investment in tankers and drilling equipment	Ps.	11,142,197		Ps.	11,142,197
Less accumulated depreciation		(1,696,089	)		(1,274,314	)
	Ps.	9,446,108		Ps.	9,867,883

Summary of Maturity Analysis of Finance Lease Payables

The liabilities relating to the assets listed above are payable in the years following December 31, 2017 as presented below:

Year	Pesos		U.S. dollars
2018		Ps. 1,867,411		94,377
2019		1,192,496		60,268
2020		1,192,496		60,268
2021		1,192,496		60,268
2022		1,192,496		60,268
2023 and thereafter		2,158,559		109,091
		8,795,954		444,540
Less: short-term unaccrued interest		331,412		16,749
Less: long-term unaccrued interest		843,480		42,630
Total capital leases		7,621,062		385,161
Less: current portion of leases (excluding interest)		1,543,881		78,026
Total long-term capital leases		Ps. 6,077,181	U.S. $	307,135

Consolidated and Separate Financial Statements

	Profit-sharing								License
As of /For the year ended December 31, 2017	EK / Balam		Block 2			Block 8			Trion		Block 3			Total
Sales:
Net sales	Ps.	7,009,464	Ps.	—		Ps.	—		Ps.	—	Ps.	—		Ps.	7,009,464
Cost of sales		5,447,955		5,953			4,845			—		511			5,459,264
Gross income (loss)		1,561,509		(5,953	)		(4,845	)		—		(511	)		1,550,200
Other income (loss), net		4,852		—			—			—		—			4,852
Administrative expenses		34,338		—			—			—		—			34,338
Operating income (loss)		1,532,023		(5,953	)		(4,845	)		—		(511	)		1,520,714
Taxes, duties and other		158,347		—			—			—		—			158,347
Net income (loss)	Ps.	1,373,676	Ps.	(5,953	)	Ps.	(4,845	)	Ps.	—	Ps.	(511	)	Ps.	1,362,367
Cash and cash equivalents	Ps.	—	Ps.	20		Ps.	25		Ps.	—	Ps.	—		Ps.	45
Accounts receivable		—		1,013			1,804			—		327			3,144
Total current assets		—		1,033			1,829			—		327			3,189
Wells, pipelines, properties, plant and equipment, net		14,869,906		—			—			4,498,234		1,107,311			20,475,451
Total assets		14,869,906		1,033			1,829			4,498,234		1,107,638			20,478,640
Suppliers		796,300		—			—			—		—			796,300
Taxes and duties payable		973		—			—			—		—			973
Other current liabilities		4,391		1,809			2,369			—		—			8,569
Total current liabilities		801,664		1,809			2,369			—		—			805,842
Total liabilities	Ps.	801,664	Ps.	1,809		Ps.	2,369		Ps.	—	Ps.	—		Ps.	805,842
Equity (deficit), net	Ps.	14,068,242	Ps.	(776	)	Ps.	(540	)	Ps.	4,498,234	Ps.	1,107,638		Ps.	19,672,798

Pemex industrial transformation [member]

Assumptions to Determine Net Present Value of Reserves Long Lived Assets

To determine the value in use of long-lived assets associated with the cash-generating units of Pemex Industrial Transformation, the net present value of cash flows was determined based on the following assumptions:

	Refining	Gas	Petrochemicals
Average crude oil Price	51.30 U.S. dollars	N.A.	N.A.
Processed volume	767 mbd	3,085 mmpcd or sour gas	Variable because the load inputs are diverse
Rate of U.S. dollar	Ps.19.7867 mxp/usd	Ps.19.7867 mxp/usd	Ps.19.7867 mxp/usd
Useful lives of the cash generating units	Average of 16 years	Average of 9 years	Average of 6 years
Discount rate	11.53% annually	10.24% annually	9.71% annually
Period	2018-2034	2018-2029	2016-2024

To determine the value in use of long-lived assets associated with the cash-generating units of Pemex Industrial Transformation, the net present value of cash flows was determined based on the following assumptions:

	Refining	Gas	Petrochemicals
Average crude oil price	52.30 U.S. dollars	N.A.	N.A.
Processed volume	1,100 mbd	3,085 mmpcd or sour gas	Variable because the load inputs are diverse
Rate of U.S. dollar	Ps.20.6640 mxp/usd	Ps.20.6640 mxp/usd	Ps.20.6640 mxp/usd
Useful lives of the cash generating units	Average of 14 years	Average of 10 years	Average of 4 years
Discount rate	12.06% annually	10.72% annually	10.29% annually
Period	2018-2034	2018-2029	2016-2024

Pemex exploration and production [member]

Assumptions to Determine Net Present Value of Reserves Long Lived Assets

To determine the value in use of long-lived assets associated with hydrocarbon extraction, the net present value of reserves is determined based on the following assumptions:

Average crude oil price	55.89 U.S. dollars/bl
Average gas price	4.92 U.S. dollars /mpc
Average condensates price	38.33 U.S. dollars /bl
Discount rate	14.40% annually

To determine the value in use of long-lived assets associated to hydrocarbon extraction, the net present value of reserves is determined based on the following assumptions:

Average crude oil price	60.24 U.S. dollars/bl
Average gas price	4.69 U.S. dollars/mpc
Average condensates price	40.22 U.S. dollars/bl
Discount rate	14.36% annually

Fixed assets [member] | Pemex industrial transformation [member]

Summary of Net Impairment and Net Reversal of Impairment

The impairment was in the following cash generating units:

Minatitlán Refinery	Ps.	(5,691,005	)
Madero Refinery		(8,480,880	)
Salina Cruz Refinery		(5,579,997	)
Total impairment of assets		(19,751,882	)
Cangrejera Petrochemical Center		3,565,355
Independencia Petrochemical Center		112,292
Arenque gas processor complex		57,039
Matapionche gas processor complex		65,104
Reversal of impairment		3,799,790
Net impairment	Ps.	(15,952,092	)

As of December 31, 2017, the value in use for the impairment or reversal of impairment of fixed assets was as follows:

Minatitlán Refinery	Ps. 32,531,925
Madero Refinery	11,420,952
Salina Cruz Refinery	12,051,597
Cangrejera Petrochemical Center	17,544,825
Independencia Petrochemical Center	3,146,413
Arenque gas processor complex	1,283,201
Matapionche gas processor complex	1,074,729
Total value in use	Ps. 79,053,642

The net reversal of impairment was in the following cash generating units:

Minatitlán Refinery	Ps. 33,165,095
Madero Refinery	21,833,892
Arenque gas processor complex	268,161
Reversal of impairment	55,267,148
Cangrejera Petrochemical Center	(2,590,870	)
Independencia Petrochemical Center	(112,292	)
Matapionche gas processor complex	(65,105	)
Total impairment of assets	(2,768,267	)
Net reversal of impairment	Ps. 52,498,881

 As of December 31, 2017, the value in use for the impairment or reversal of impairment of fixed assets was as follows:

Minatitlán Refinery	Ps. 43,856,284
Madero Refinery	33,961,120
Salina Cruz Refinery	36,057,410
Cangrejera Petrochemical Center	2,441,686
Independencia Petrochemical Center	1,706,687
Arenque gas processor complex	473,499
Matapionche gas processor complex	572,909
Total value in use	Ps. 119,069,595

PEMEX [member]

Summary of Net Impairment and Net Reversal of Impairment

i. As of December 31, 2017, the net impairment was as follows:

	Impairment			Reversal of impairment		Net Impairment
Pemex Exploration and Production	Ps.	(129,350,315	)	Ps.	—	Ps.	(129,350,315	)
Pemex Industrial Transformation		(19,751,882	)		3,799,790		(15,952,092	)
AGRO		(4,206,653	)		—		(4,206,653	)
Pemex Fertilizers		(1,935,500	)		—		(1,935,500	)
Total	Ps.	(155,244,350	)	Ps.	3,799,790	Ps.	(151,444,560	)

ii. As of December 31, 2016, the net reversal of impairment was as follows:

	Impairment			Reversal of impairment		Reversal of impairment
Pemex Exploration and Production		Ps. (16,872,238	)		Ps. 288,581,670		Ps. 271,709,432
Pemex Industrial Transformation		(2,768,267	)		55,267,148		52,498,881
Pemex Logistics		—			5,829,520		5,829,520
Pemex Ethylene		—			1,276,510		1,276,510
Total		Ps. (19,640,505	)		Ps. 350,954,848		Ps. 331,314,343

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Intangible Assets (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Schedule of Intangible Assets are Wells Unassigned to a Reserve

At December 31, 2017 and 2016, intangible assets are wells unassigned to a reserve, which amounted Ps. 9,088,563 and Ps. 8,639,242, respectively as follows:

	2017			2016
Wells unassigned to a reserve:
Balance at the beginning of period	Ps.	8,639,242		Ps.	14,304,961
Additions to construction in progress		20,553,952			20,526,300
Transfers against expenses		(3,663,986	)		(9,798,246	)
Transfers against fixed assets		(16,440,645	)		(16,393,773	)
Balance at the end of period	Ps.	9,088,563		Ps.	8,639,242

XML

Long-Term Notes Receivable and Other Assets (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Summary of Long-Term Notes Receivable

As of December 31, 2017 and 2016, the balance of long-term notes receivable was as follows:

	2017		2016
Promissory notes issued by the Mexican Government	Ps	. 147,274,076	Ps	.140,578,871
Other long-term notes receivable(1)		1,218,833		8,028,731
Total long-term notes receivable	Ps	. 148,492,909	Ps	.148,607,602

(1) For 2016, primarily CENAGAS.

Summary of Promissory Notes Issued

Promissory notes issued by the Mexican Government

	2017		2016
Total promissory notes	Ps	.149,796,282	Ps	.142,124,620
Less: current portion of notes receivable(1)		2,522,206		1,545,749
Long-term promissory notes	Ps	.147,274,076	Ps	.140,578,871

(1) The current portion of the promissory notes and the total yield payments are allocated under sundry debtors in accounts receivable, net (see Note 7).

Summary of Promissory Notes Maturity Dates and Annual Rates

As of December 31, 2017 and 2016, these promissory notes at discount valued amounted to Ps. 147,274,076 and Ps. 140,578,871, respectively. PEMEX intends is to hold them to maturity. These promissory notes will be converted into cash with annual maturity dates ranging from 2018 to 2042 and annual rates ranging from 4.65% to 7.03% in 2017 and ranging from 2017 to 2042 and annual rates ranging from 4.35% to 7.04% in 2016, as follows:

As of December 31, 2017
Number of Promissory Notes	Maturity	Yield Rate Range	Principal Amount
1	2018	4.65%	Ps.	2,522,206
1	2019	5.14%		3,580,302
1	2020	5.39%		4,421,320
1	2021	5.57%		5,238,081
1	2022	5.74%		5,804,485
5	2023 to 2027	5.87% to 6.32%		34,196,434
5	2028 to 2032	6.47% to 6.81%		35,338,617
5	2033 to 2037	6.85% to 7.03%		32,789,697
5	2038 to 2042	7.02% to 6.94%		25,905,140
	Total promissory notes			149,796,282
	Less: current portion		Ps.	2,522,206
	Long-term notes receivable		Ps.	147,274,076

As of December 31, 2016
Number of Promissory Notes	Maturity	Yield Rate Range	Principal Amount
1	2017	4.35%	Ps.	1,545,749
1	2018	4.65%		2,408,634
1	2019	5.14%		3,402,849
1	2020	5.39%		4,192,132
1	2021	5.57%		4,957,840
5	2022 to 2026	4.74% a 6.11%		30,986,252
5	2027 to 2031	6.32% a 6.77%		33,280,216
5	2032 to 2036	6.81% a 7.00%		31,370,504
6	2037 to 2042	6.94% a 7.04%		29,980,444
	Total promissory notes		Ps.	142,124,620
	Less: current portion			1,545,749
	Long-term notes receivable		Ps.	140,578,871

Summary of Other Assets

At December 31, 2017 and 2016, the balance of other assets was as follows:

	2017		2016
Payments in advance	Ps.	4,683,117	Ps.	2,558,767
License		2,162,151		1,813,605
Rights-of-way		1,967,304		1,940,157
Other		2,672,605		3,200,116
Total other assets	Ps.	11,485,177	Ps.	9,512,645

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Debt (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Summary of Long-term Debt

As of December 31, 2017, long-term debt was as follows:

				Pesos		Foreign currency
	Rate of interest(1)	Maturity		(thousands)		(thousands)
U.S. dollars
Bonds	Fixed from 1.7% to 9.5% and LIBOR plus 0.35% to 3.65%		Various to 2047		Ps. 1,138,845,231	US$	57,556,097
Purchasing loans	LIBOR plus 0.85%		Various to 2018		25,722,710		1,300,000
Project financing	Fixed from 2.35% to 3.81% and LIBOR plus 0.24% to 1.75%		Various to 2025		64,974,389		3,283,741
Direct loans	Fixed from 5.25% to 5.44% and LIBOR plus 1.65%		Various to 2020		43,141,231		2,180,315
Syndicated loans	LIBOR plus 0.85%		Various to 2020		39,347,774		1,988,597
Bank loans	Fixed from 3.5% to 5.28%		Various to 2023		3,451,629		174,442
Financial leases	Fixed from 0.38% to 1.99%		Various to 2025		7,621,062		385,161
Lease-back (See Financing activities for 2016 l) and m))(4)	Fixed from 0.45% to 0.7%		Various to 2036		32,677,268		1,651,476
Total financing in U.S. dollars					1,355,781,294	US$	68,519,829
Euros
Bonds	Fixed from 1.875% to 5.5%		Various to 2030		287,386,195	€	12,097,975
Project financing	Fixed from 2.1% to 5.11%		Various to 2023		11,879,379		500,081
Total financing in Euros					299,265,574	€	12,598,056
Japanese yen:
Bonds	Fixed from 0.54% to 3.5% and LIBOR yen plus 0.75%		Various to 2026		30,541,407	¥	173,827,018
Pesos
Certificados bursátiles	Mexican Government Treasury Certificates (“Cetes”) , TIIE(1) less 0.06% to 1.35%, and fixed at 7.19% to 9.1%		Various to 2026		Ps. 149,564,918
Direct loans	Fixed at 6.55% and TIIE plus 0.85% to 1.25%		Various to 2025		28,597,423
Syndicated loans	TIIE plus 0.95		Various to 2025		33,646,107
Total financing in pesos					Ps. 211,808,448
Unidades de Inversión Certificados bursátiles
Certificados bursátiles	Zero rate and Fixed at 3.02% to 5.23%		Various to 2035		57,197,211
Other currencies:
Bonds	Fixed from 1.5% to 8.25%		Various to 2025		47,148,936
Total principal in pesos(2)					2,001,742,870
Plus: accrued interest					32,078,624
Notes payable to contractors(3)					4,053,577
Total principal and interest					2,037,875,071
Less: short-term maturities					122,957,558
Current portion of notes payable to contractors(3)					2,173,285
Accrued interest					32,078,624
Total short-term debt and current portion of long-term debt					157,209,467
Long-term debt (Note 16(c))					Ps. 1,880,665,604

As of December 31, 2016, long-term debt was as follows:

	Rate of interest(1)	Maturity	Pesos (thousands)		Foreign currency (thousands)
U.S. dollars
Bonds	Fixed from 3.125% to 9.5% and LIBOR plus 0.35% to 2.02%	Various to 2046		Ps. 1,131,389,914	U.S. $	54,751,738
Purchasing loans	LIBOR plus 0.8% to 0.85%	Various to 2016		2,479,680		120,000
Project financing	Fixed from 2.35% to 5.45% and LIBOR plus 0.01% to 1.71%	Various to 2021		84,711,684		4,099,481
Direct loans	Fixed at 5.44% and LIBOR plus 1.0%	Various to 2018		33,100,587		1,601,848
Syndicated loans	LIBOR plus 0.85%	Various to 2020		41,056,571		1,986,865
Bank loans	Fixed from 3.5% to 5.28%	Various to 2023		4,339,826		210,019
Financial leases	Fixed from 0.38% to 1.99%	Various to 2025		9,559,060		462,595
Lease-back (See Financing activities for 2016 l) and m))(4)	Fixed from 0.45% to 0.7%	Various to 2036		35,513,114		1,718,598
Total financing in U.S. dollars				1,342,150,436	U.S. $	64,951,144
Euros
Bonds	Fixed from 3.125% to 6.375%	Various to 2030		196,317,016	€	9,058,388
Project financing	Fixed at 2%	Various to 2016		10,836,200		500,000
Total financing in Euros				207,153,216	€	9,558,388
Japanese yen:
Bonds	Fixed at 3.5% and LIBOR yen plus 0.75%	Various to 2023		30,800,746	¥	173,809,300
Project financing	Fixed at 1.56% and Prime Rate yen plus 2.56%	Various to 2017		517,286		2,919,056
Total financing in yen				31,318,032	¥	176,728,356
Pesos
Certificados bursátiles	Mexican Government Treasury Certificates (“Cetes”) , TIIE(1) less 0.06% to 0.35%, and fixed at 7.19% to 9.15%	Various to 2026	Ps.	173,151,985
Direct loans	Fixed at 6.55% and TIIE plus 0.55% to 1.25%	Various to 2025		45,563,848
Syndicated loans	TIIE plus 0.95	Various to 2025		38,538,961
Revolved loans	TIIE plus 0.55	To 2016		20,000,000
Total financing in pesos			Ps.	277,254,794
Unidades de Inversión Certificados bursátiles
Certificados bursátiles	Zero rate and Fixed at 3.02% to 5.23%	Various to 2035		53,703,421
Other currencies:
Bonds	Fixed from 2.5% to 8.25%	Various to 2022		36,786,665
Total principal in pesos(2)				1,948,366,564
Plus: accrued interest				27,815,467
Notes payable to contractors(3)				6,988,699
Total principal and interest				1,983,170,730
Less: short-term maturities				144,169,619
Current portion of notes payable to contractors(3)				4,181,102
Accrued interest				27,815,467
Total short-term debt and current portion of long-term debt				176,166,188
Long-term debt (Note 16(c))			Ps.	1,807,004,542

Summary of Notes Payable to Contractors

(3) The total amounts of notes payable to contractors as of December 31, 2017 and 2016, current and long-term, are as follows:

	2017		2016
Total notes payable to contractors(a)(b)		Ps.4,053,577		Ps.6,988,699
Less: current portion of notes payable to contractors		2,173,285		4,181,102
Notes payable to contractors (long-term)		Ps.1,880,292		Ps.2,807,597

(a) PEMEX has entered into FPWCs pursuant to which the hydrocarbons and construction in progress are property of Pemex Exploration and Production. Pursuant to the FPWC, the contractors manage the work in progress, classified as development, infrastructure and maintenance. As of December 31, 2017 and 2016, PEMEX had an outstanding amount payable of Ps. 1,678,843 and Ps. 3,986,565, respectively.

(b) During 2007, Pemex-Exploration and Production contracted for the purchase of a Floating Production Storage and Offloading (“FPSO”) vessel. The investment in the vessel totaled U.S. $723,575. As of December 31, 2017 and 2016, the outstanding balances owed to the contractor were Ps. 2,374,734 (U.S. $120,017) and Ps. 3,002,134 (U.S. $145,283), respectively. In accordance with the contract, the estimated future payments are as follows:

Summary of Estimated Future Contract Payments

(b) During 2007, Pemex-Exploration and Production contracted for the purchase of a Floating Production Storage and Offloading (“FPSO”) vessel. The investment in the vessel totaled U.S. $723,575. As of December 31, 2017 and 2016, the outstanding balances owed to the contractor were Ps. 2,374,734 (U.S. $120,017) and Ps. 3,002,134 (U.S. $145,283), respectively. In accordance with the contract, the estimated future payments are as follows:

Year	Amount
2018	U.S.$	25,267
2019		25,267
2020		25,267
2021		25,267
2022		18,949
Total	U.S $	120,017

Summary of Outstanding Liability Transaction Payable

The outstanding liability for this transaction is payable as follows:

Years	Pesos		U.S. dollars
2018		Ps. 3,957,317	U.S. $	199,999
2019		3,886,037		196,396
2020		3,886,037		196,396
2021		3,886,037		196,396
2022		3,886,037		196,396
2023 and thereafter		39,450,325		1,993,781
		58,951,790		2,979,364
Less: short-term unaccrued interest		2,399,475		121,267
Less: long-term unaccrued interest		23,875,047		1,206,621
Total financing		32,677,268		1,651,476
Less: short-term portion of financing (excluding interest)		1,557,842		78,732
Total long term financing		Ps. 31,119,426	U.S.$	1,572,744

Summary of Foreign Currency Translation

(5) As of December 31, 2017 and 2016, PEMEX used the following exchange rates to translate the outstanding balances in foreign currencies to pesos in the statement of financial position:

	2017		2016
U.S. dollar		Ps. 19.7867		Ps. 20.6640
Japanese yen		0.1757		0.1772
Pounds sterling		26.7724		25.3051
Euro		23.7549		21.6724
Swiss francs		20.2992		20.1974
Canadian dollar		15.7858		15.2896
Australian dollar		15.4752		14.8842

Summary of Maturities of Long Term Debt Principal Outstanding and Accrued Interest

2018

2019

2020

2021

2022

2023 and thereafter

Total

Maturity of the total principal outstanding and accrued interest as of December 31, 2017, for each of the years ending December 31.

Ps.157,209,467

Ps.159,403,397

Ps,209,915,748

Ps.185,307,669

Ps.158,761,145

Ps.1,167,277,645

Ps.2,037,875,071

Summary of Changes in Consolidated Debt

The following table presents the roll-forward of total debt of PEMEX for each of the year ended December 31, 2017 and 2016, which includes short and long-term debt:

	2017(i)			2016(i)
Changes in total debt:
At the beginning of the year		Ps.1,983,170,730			Ps.1,493,381,835
Cash flows:
Loans obtained—financing institutions		704,715,468			829,579,084
Loans obtained—financing lease		—			21,924,053
Debt payments		(642,059,819	)		(614,987,329	)
Interest paid		(108,910,417	)		(88,757,428	)
Non-cash flows:
Foreign exchange		(16,685,439	)		243,182,764
Accrued interest		117,644,548			98,847,751
At the end of the year		Ps.2,037,875,071			Ps.1,983,170,730

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Derivative Financial Instruments (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Details of Interest Rate Sensitivity

INTEREST RATE and CURRENCY DFIs

Interest rate sensitivity to + 10 bp
	Interbank Yield Curves							PEMEX Curves Sensitivity debt
Currency	Sensitivity debt		Sensitivity DFIs			Sensitivity net
in thousands U.S. dollars
CHF		3,144		(3,144	)		—		3,030
Euro		100,081		(84,962	)		15,119		82,839
Pound Sterling		7,691		(7,073	)		618		6,587
Yen		8,542		(3,972	)		4,570		6,877
Peso		43,774		2,039			45,813		42,012
UDI		16,496		(11,586	)		4,910		15,453
U.S. dollar		785,508		89,880			875,388		416,052

Details of Interest Rate and Currency Derivative Financial Instruments

INTEREST RATE and CURRENCY DFIs

	Interbank Yield Curves											PEMEX Curves 1% Debt
Currency	1% Debt			1% DFIs		1% Net			VaR 95% Net
in thousands U.S. dollars
CHF		(13,943	)		13,943		—			—			(13,624	)
Euro		(187,988	)		165,894		(22,094	)		(19,744	)		(167,068	)
Pound Sterling		(13,822	)		13,042		(780	)		(666	)		(12,322	)
Yen		(16,914	)		11,470		(5,444	)		(4,398	)		(14,859	)
Peso		(135,974	)		1,409		(134,565	)		(162,336	)		(133,525	)
UDI		(29,485	)		25,358		(4,127	)		(5,038	)		(28,573	)

Details of Current and Potential Exposures and Aggregated By Credit Rating

The current and potential exposures, aggregated by credit rating, are as follows:

Maximum Credit Exposure by term in Petróleos Mexicanos
Rating	Current		Less than 1 year		1-3 years		3-5 years		5-7 years		7-10 years		More than 10 years
in thousands U.S. dollars
A		257,424		976,230		1,298,110		1,314,296		578,548		482,959		—
A-		138,850		235,594		191,681		228,801		223,751		257,465		—
BBB+		310,705		1,010,356		1,540,015		1,349,311		1,243,898		1,115,559		78,831
BBB		2,183		18,626		20,064		18,092		—		—		—

Details of Notional Amounts of Investments in Domestic Currency and Organized By the Credit Ratings of the Issuances

As of December 31, 2017, the notional amounts of investments in domestic currency, organized by the credit ratings of the issuances, were as follows:

Credit rating of issuances*	Notional amount
mxAAA		Ps.        811,548
mxAA		200,876
mxA		271,275
* Minimum S&P, Moody’s and Fitch credit rating.

Schedule of Current and Potential Exposure, Aggregated By Credit Rating and Derivative Financial Instruments

Maximum Credit Exposure by term in Pemex Industrial Transformation
Rating	Current		Less than 1 year		1-3 years		3-5 years		5-7 years		7-10 years		More than 10 years
in thousands U.S. dollars
A		27		27		—		—		—		—		—
A-		541		541		306		—		—		—		—
BBB+		25		25		1		—		—		—		—

Details of Quantitative Disclosure of Debt Cash Flow's Maturities

Quantitative Disclosure of Debt Cash Flow’s Maturities as of December 31, 2017⁽¹⁾

	Year of expected maturity date
	2018		2019		2020		2021		2022		2023 thereafter		Total carrying value			Fair value
Liabilities
Outstanding debt
Fixed rate (U.S. dollars)	Ps	53,465,817	Ps	59,498,256	Ps	60,290,621	Ps	95,232,448	Ps	84,076,050	Ps	808,836,547	Ps	1,161,399,739		Ps	. 1,213,404,769
Average interest rate (%)														5.7747	%
Fixed rate (Japanese yen)		—		—		—		—		—		19,296,607		19,296,607			18,040,398
Average interest rate (%)														1.3485	%
Fixed rate (Pounds)		—		—		—		—		9,345,839		11,952,816		21,298,655			24,381,394
Average interest rate (%)														5.7246	%
Fixed rate (pesos)		—		—		10,033,017		20,376,655		1,999,098		88,349,072		120,757,842			171,683,692
Average interest rate (%)														7.4876	%
Fixed rate (UDIs)		—		18,477,076		4,764,175		3,874,313		—		30,081,647		57,197,211			56,536,905
Average interest rate (%)														2.7458	%
Fixed rate (euros)		1,043		32,042,196		30,801,894		41,508,857		23,655,950		171,255,634		299,265,574			330,573,998
Average interest rate (%)														3.6736	%
Fixed rate (Swiss Francs)		4,565,075		6,088,686		12,149,953		3,046,567		—		—		25,850,281			26,957,785
Average interest rate (%)														1.8387	%
Fixed rate (Australian dollars)		—		—		—		—		—		—		—			—
Average interest rate (%)		—		—		—		—		—		—		—			—
Total fixed rate debt		58,031,935		116,106,214		118,039,660		164,038,840		119,076,937		1,129,772,323		1,705,065,909			1,841,578,940
Variable rate (U.S. dollars)		58,364,536		15,302,101		62,289,546		12,809,666		31,289,725		18,379,557		198,435,131			206,254,219
Variable rate (Japanese yen)		—		—		11,244,800		—		—		—		11,244,800			11,361,079
Variable rate (pesos)		8,734,371		27,995,083		18,341,742		8,459,163		8,394,483		19,125,764		91,050,606			94,188,981
Total variable rate debt		67,098,907		43,297,184		91,876,088		21,268,829		39,684,208		37,505,321		300,730,537			311,804,280
Total debt	Ps	. 125,130,842	Ps	. 159,403,398	Ps	. 209,915,748	Ps	. 185,307,669	Ps	. 158,761,145	Ps	.1,167,277,644	Ps	. 2,005,796,446		Ps	.2,153,383,220

Note: Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2017 of: Ps. 19.7867 = U.S. $1.00; Ps. 0.1757 = 1.00 Japanese yen; Ps. 26.7724 = 1.00 Pound sterling; Ps. $ 5.934551 = 1.00 UDI; Ps. 23.7549 = 1.00 euro; Ps. 20.2992 = 1.00 Swiss Franc; and Ps. 15.4752 = 1.00 Australian dollar.

Source: PEMEX

Quantitative Disclosure of Debt Cash Flow’s Maturities as of December 31, 2016⁽¹⁾

	Year of expected maturity date
	2017		2018		2019		2020		2021		2022 thereafter		Total carrying value			Fair value
Liabilities
Outstanding debt
Fixed rate (U.S. dollars)		Ps 15,759,027	Ps	86,161,096	Ps	65,642,616	Ps	62,440,943	Ps	98,858,992	Ps	826,093,574	Ps	1,154,956,248		Ps	1,137,936,275
Average interest rate (%)														5.6541	%
Fixed rate (Japanese yen)		517,286		—		—		—		—		19,459,306		19,976,592			17,336,203
Average interest rate (%)														1.3665	%
Fixed rate (Pounds)		—		—		—		—		—		8,825,434		8,825,434			11,373,345
Average interest rate (%)														8.2500	%
Fixed rate (pesos)		—		—		—		10,048,950		20,457,671		90,393,507		120,900,128			160,930,040
Average interest rate (%)														7.4878	%
Fixed rate (UDIs)		—		—		17,319,897		4,464,787		3,630,557		28,288,180		53,703,421			50,809,979
Average interest rate (%)														4.0559	%
Fixed rate (euros)		26,006,880		—		29,198,138		28,061,554		—		123,886,644		207,153,216			216,100,006
Average interest rate (%)														3.9581	%
Fixed rate (Swiss Francs)		—		4,539,022		6,056,338		12,102,748		3,031,480		—		25,729,588			26,469,543
Average interest rate (%)														1.8385	%
Fixed rate (Australian dollars)		2,232,195		—		—		—		—		—		2,232,195			2,346,390
Average interest rate (%)		—		—		—		—		—		—		6.1250	%		—
Total fixed rate debt		44,515,388		90,700,118		118,216,989		117,118,982		125,978,700		1,096,946,645		1,593,476,822			1,623,301,781
Variable rate (U.S. dollars)		38,811,320		27,907,661		15,984,547		52,726,647		13,366,336		45,385,885		194,182,396			195,838,382
Variable rate (Japanese yen)		—		—		—		11,341,440		—		—		11,341,440			11,025,531
Variable rate (euros)		—		—		—		—		—		—		—			—
Variable rate (pesos)		65,024,075		8,742,191		28,007,709		18,347,822		8,468,176		27,764,693		156,354,666			158,109,920
Total variable rate debt		103,835,395		36,649,852		43,992,256		82,415,909		21,834,512		73,150,578		361,878,502			364,973,833
Total debt	Ps.	148,350,783	Ps.	127,349,970	Ps.	162,209,245	Ps.	199,534,891	Ps.	147,813,212	Ps.	1,170,097,223	Ps.	1,955,355,324		Ps.	1,988,275,614

Note: Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2016 of: Ps. 20.664 = U.S. $1.00; Ps. 0.17721 = 1.00 Japanese yen; Ps. 25.30513 = 1.00 Pound sterling; Ps. $ 5.562883 = 1.00 UDI; Ps. 21.6724 = 1.00 euro; Ps. 20.19744= 1.00 Swiss Franc; and Ps. 14.88428 = 1.00 Australian dollar.

Summary of Quantitative Disclosure of Cash Flow's Maturities

Quantitative Disclosure of Cash Flow’s Maturities from Derivative Financial Instruments Held or Issued for Purposes Other than Trading as of December 31, 2017⁽¹⁾⁽²⁾

	Year of expected maturity date																		Total Notional Amount		Fair Value(3)
	2018			2019			2020			2021			2022			2023 Thereafter
Hedging instruments(2)(4)
Interest rate DFIs
Interest rate swaps (U.S. dollars)
Variable to fixed		Ps. 4,704,170			Ps. 4,717,321			Ps. 4,730,857			Ps. 4,686,396			Ps 4,570,070			Ps 10,143,209			Ps. 33,552,022		Ps. 388,851
Average pay rate		3.16	%		3.18	%		3.20	%		3.22	%		3.26	%		3.48	%		N.A.		N.A.
Average receive rate		3.19	%		3.44	%		3.69	%		3.81	%		3.95	%		4.48	%		N.A.		N.A.
Interest rate swaps (pesos)
Variable to fixed		—			—			—			—			—			—			—		—
Average pay rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Average receive rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Currency DFIs
Cross-currency swaps
Receive euros/Pay U.S. dollars		—			29,898,198			28,719,208			36,902,690			21,302,856			161,617,172			278,440,124		19,065,727
Receive Japanese yen/ Pay U.S. dollars		—			—			13,039,563			—			—			4,775,551			17,815,114		(1,670,533	)
Receive Pounds sterling/ Pay U.S. dollars		—			—			—			—			10,310,216			11,706,999			22,017,215		1,151,096
Receive UDI/ Pay pesos		—			23,740,341			7,292,520			3,000,000			—			20,605,166			54,638,028		(4,720,592	)
Receive Swiss francs/ Pay U.S. dollars		4,535,474			6,501,082			11,548,658			2,994,374			—			—			25,579,588		400,316
Receive Australian dollars/ Pay U.S. dollars		—			—			—			—			—			—			—		—
Currency Options
Buy Put, Sell Put and Sell Call on Japanese yen		—			—			—			—			—			14,046,320			14,046,320		48,715
Buy call, Sell call and Sell Put on euros		—			—			—			41,567,998			—			59,382,855			100,950,853		4,919,444
Sell Call on Pound sterling		—			—			—			—			—			12,031,728			12,031,728		(239,626	)
Currency Forwards
Receive U.S. dollars / Pay pesos		59,360,100			—			—			—			—			—			59,360,100		(2,006,461	)

N.A. = not applicable.

Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2017 of: Ps. 19.7867 = U.S. $1.00 and Ps. 23.7549 = 1.00 euro.

(2) PEMEX’s management uses these DFIs to hedge market risk; however, these DFIs do not qualify for accounting purposes as hedges and are recorded in the financial statements as entered into for trading purposes.

(3) Positive numbers represent a favorable fair value to PEMEX.

(4) PMI’s risk management policies and procedures establish that DFIs should be used only for hedging purposes; however DFIs are not recorded as hedges for accounting purposes.

Source: PEMEX

Quantitative Disclosure of Cash Flow’s Maturities from Derivative Financial Instruments Held or Issued for Purposes Other than Trading as of December 31, 2016⁽¹⁾⁽²⁾

	Year of expected maturity date																		Total Notional Amount		Fair Value(3)
	2017			2018			2019			2020			2021			2022 Thereafter
Hedging instruments(2)(4)
Interest rate DFIs
Interest rate swaps (U.S. dollars)
Variable to fixed		Ps. 4,899,645			Ps. 4,912,743			Ps. 4,926,477			Ps. 4,940,613			Ps 4,894,180			Ps 15,365,634			Ps. 39,939,292		Ps. 164,716
Average pay rate		2.76	%		2.66	%		3.35	%		3.83	%		4.04	%		4.57	%		N.A.		N.A.
Average receive rate		2.95	%		2.99	%		3.03	%		3.06	%		3.11	%		3.33	%		N.A.		N.A.
Interest rate swaps (pesos)
Variable to fixed		—			—			—			—			—			—			—		—
Average pay rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Average receive rate		N.A.			N.A.			N.A.			N.A.			N.A.			N.A.			N.A.		N.A.
Currency DFIs
Cross-currency swaps
Receive euros/Pay U.S. dollars		34,775,198			—			31,223,821			29,992,556			—			133,024,913			229,016,488		(16,484,533	)
Receive Japanese yen/ Pay U.S. dollars		532,711			—			—			17,697,534			—			4,987,289			23,217,534		(6,132,633	)
Receive Pounds sterling/ Pay U.S. dollars		—			—			—			—			—			10,767,349			10,767,349		(211,207	)
Receive UDI/ Pay pesos		—			—			23,740,341			3,540,220			3,000,000			14,313,198			44,593,759		(2,132,236	)
Receive Swiss francs/ Pay U.S. dollars		—			4,736,567			6,789,326			12,060,700			3,127,139			—			26,713,732		(789,449	)
Receive Australian dollars/ Pay U.S. dollars		2,459,429			—			—			—			—			—			2,459,429		(126,796	)
Currency Options
Buy Put, Sell Put and sell Call on yen		—			—			—			—			—			14,133,580			14,133,580		(301,131	)

N.A. = not applicable.

Numbers may not total due to rounding.

(1) The information in this table has been calculated using exchange rates at December 31, 2016 of: Ps. 20.664 = U.S. $1.00 and Ps. 21.6724 = 1.00 euro.

(2) PEMEX’s management uses these DFIs to hedge market risk; however, these DFIs do not qualify for accounting purposes as hedges and are recorded in the financial statements as entered into for trading purposes.

(3) Positive numbers represent a favorable fair value to PEMEX.

(4) PMI’s risk management policies and procedures establish that DFIs should be used only for hedging purposes; however DFIs are not recorded as hedges for accounting purposes.

Summary of Fair Values and Notional Amounts of DFIs that were designated as non-hedges

		December 31, 2017						December 31, 2016
DFI	POSITION	Notional Amount			Fair Value			Notional Amount			Fair Value
Interest rate swaps	PEMEX pays fixed in U.S. dollar and receives floating in 3-month U.S. dollar LIBOR + spread.		Ps.16,695,028			Ps.   79,448			Ps.20,018,250		Ps.	(90,451	)
Interest rate swaps	PEMEX pays fixed in U.S. dollar and receives floating in 6-month U.S. dollar LIBOR + spread.		15,433,626			332,273			18,132,660			312,210
Cross-currency swaps	PEMEX pays fixed in pesos and receives notional in UDI.		23,740,341			(4,504,151	)		23,740,341			(4,815,373	)
Cross-currency swaps	PEMEX pays the 28-day TIIE + spread in pesos and receives fixed in UDI.		30,897,687			(216,441	)		20,853,418			2,683,138
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in Japanese yen.		4,775,551			134,461			5,520,000			(116,507	)
Cross-currency swaps	PEMEX pays floating in 6-month U.S. dollar LIBOR + spread and receives floating in 6-month yen LIBOR + spread.		13,039,563			(1,804,993	)		17,697,534			(6,016,126	)
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in euro.		278,440,124			19,065,727			229,016,488			(16,484,533	)
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in Pound sterling.		11,706,999			590,113			—			—
Cross-currency swaps	PEMEX pays floating in 6-month U.S. dollar LIBOR + spread and receives fixed in Pound sterling.		10,310,216			560,982			10,767,349			(211,207	)
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in CHF.		25,579,588			400,316			26,713,732			(789,449	)
Cross-currency swaps	PEMEX pays fixed in U.S. dollar and receives fixed in AUD.		—			—			2,459,429			(126,796	)
Currency Options	PEMEX Buy Put, Sell Put and Sell Call on Japanese yen.		14,046,320			48,715			14,133,580			(301,131	)
Currency Options	PEMEX Buy call, Sell call and Sell Put on euros.		100,950,853			4,919,444			—			—
Currency Options	PEMEX Sell Call on Pound sterling		12,031,728			(239,626	)		—			—
Currency Forward	PEMEX pays Pesos and receives U.S. dollar.		59,360,100			(2,006,461	)		—			—
Natural gas swaps	PEMEX receives fixed.		(51,724	)		6,934			(160,214	)		(25,145	)
Natural gas swaps	PEMEX receives floating.		50,846			(6,114	)		157,545			27,869
Natural gas options	PEMEX Long Call.		18,625			398			73,653			11,548
Natural gas options	PEMEX Short Call.		(18,625	)		(397	)		(73,653	)		(11,488	)
Interest rate swaps	PEMEX pays fixed in U.S. dollar and receives floating in U.S. dollar LIBOR 1M.		1,423,368			(22,870	)		1,788,382			(57,043	)
						Ps.17,337,760					Ps.	(26,010,486	)

	December 31, 2017					December 31, 2016
DFI	Volume (MMb)		Fair Value			Volume (MMb)		Fair Value
Crude Oil Options		153.56	Ps.	(5,010,187	)		—		—

			December 31, 2017					December 31, 2016
DFI	Market		Volume (MMb)		Fair value			Volume (MMb)		Fair value
Futures		Exchange traded		2.1	Ps	. (141,693	)		—	Ps.	—
Petroleum Products Swaps		Exchange traded		1.3	Ps	.   (99,680	)		4.1	Ps.	(688,016	)

Notes: Numbers may not total due to rounding.

(1) The fair value of the Futures and the Petroleum Products Swaps, was recognized as “Cash and cash equivalents” in the statement of financial position because PEMEX considered these financial assets to be fully liquid.

Summary of Location on the Consolidated Statement of Financial Position and the Fair Value of DFIs

The following table presents the fair value of PEMEX’s DFIs that are showed on the consolidated statement of financial position in derivative financial instruments (including both DFIs that have not reached maturity and those that have reached maturity but have not been settled), as of December 31, 2017 and 2016:

	Derivatives assets Fair value
	2017		2016
Derivatives not designated as hedging instruments
Crude oil options	Ps.	397,630	Ps.	—
Currency options		4,968,159		—
Natural gas options		398		11,548
Cross-currency swaps		24,126,452		4,503,550
Natural gas swaps		7,003		30,162
Propane swaps		—		—
Interest rate swaps		411,721		312,210
Others		202,091		—
Total derivatives not designated as hedging instruments		30,113,454		4,857,470
Total assets	Ps.	30,113,454	Ps.	4,857,470

	Derivatives liabilities Fair value
	2017			2016
Derivatives not designated as hedging instruments
Forwards	Ps.	(2,006,461	)	Ps.	—
Futures		—			—
Crude oil options		(5,407,817	)		—
Currency options		—			(301,131	)
Natural gas options		(397	)		(11,488	)
Cross-currency swaps		(10,301,983	)		(30,380,405	)
Natural gas swaps		(6,182	)		(27,438	)
Propane swaps		—			—
Interest rate swaps		(22,870	)		(147,494	)
Others		(269	)		—
Total derivatives not designated as hedging instruments		(17,745,979	)		(30,867,956	)
Total liabilities	Ps.	(17,745,979	)	Ps.	(30,867,956	)
Net total	Ps.	12,367,475		Ps.	(26,010,486	)

Summary of Net Gain (Loss) Recognized in Income on Derivative Financial Instruments

The following tables present the net gain (loss) recognized in income on PEMEX’s DFIs for the years ended December 31, 2017, 2016 and 2015, in the consolidated statement of comprehensive income which is presented in the line “Derivative financial instruments (cost) income, net”:

Derivatives not designated as hedging instruments	Amount of gain (loss) recognized in the Statement of comprehensive income
	2017			2016			2015
Forwards	Ps.	(1,976,241	)	Ps.	—		Ps.	—
Futures		(779,950	)		(1,925,969	)		1,387,177
Crude oil options		(3,771,604	)		—			—
Currency options		5,255,931			(298,789	)		—
Natural gas options		673			(671	)		4,786
Cross-currency swaps		27,747,290			(11,633,605	)		(21,358,898	)
Natural gas swaps		1,780			831			4,355
Propane swaps		—			(3,805	)		(1,136,188	)
Interest rate swaps		(34,306	)		(138,979	)		(351,109	)
Others		(1,105,249	)		—			—
Total	Ps.	25,338,324		Ps.	(14,000,987	)	Ps.	(21,449,877	)

Schedule of Financial Assets and Liabilities Measured at Fair Value and Indicate the Fair Value Hierarchy of the Inputs Utilized to Determine the Fair Values

The following tables present information about PEMEX’s financial assets and liabilities measured at fair value and indicate the fair value hierarchy of the inputs utilized to determine the fair values as of December 31, 2017 and 2016.

	Fair value hierarchy							Total as of 2017
	Level 1		Level 2			Level 3
Assets:
Derivative financial instruments	Ps.	—	Ps.	30,113,454		Ps.	—	Ps.	30,113,454
Available-for-sale financial assets		—		1,056,918			—		1,056,918
Liabilities:
Derivative financial instruments		—		(17,745,979	)		—		(17,745,979	)
	Fair value hierarchy							Total as of 2016
	Level 1		Level 2			Level 3
Assets:
Derivative financial instruments	Ps.	—	Ps.	4,857,470		Ps.	—	Ps.	4,857,470
Available-for-sale financial assets		6,463,096		2,417,123			—		8,880,219
Liabilities:
Derivative financial instruments		—		(30,867,956	)		—		(30,867,956	)

Schedule of Carrying Value and the Estimated Fair Value of the Remaining Financial Assets and Liabilities

The following table shows the carrying value and the estimated fair value of the remaining financial assets and liabilities, which are not valued at fair value, as of December 31, 2017 and 2016:

	2017				2016
	Carrying value		Fair value		Carrying value		Fair value
Assets:
Cash and cash equivalents	Ps.	97,851,754	Ps.	97,851,754	Ps.	163,532,513	Ps.	163,532,513
Accounts receivable, net		170,645,234		170,645,234		133,220,527		133,220,527
Long-term notes receivable		148,492,909		148,492,909		148,607,602		148,607,602
Liabilities:
Suppliers		139,955,378		139,955,378		151,649,540		151,649,540
Accounts and accrued expenses payable		23,211,401		23,211,401		18,666,607		18,666,607
Short-term debt and current portion of long-term debt		157,209,467		157,209,467		176,166,188		176,166,188
Long-term debt		1,880,665,604		1,996,173,753		1,807,004,542		1,812,109,426

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Employee Benefits (Tables)

12 Months Ended

Dec. 31, 2017

Summary of Amounts Associated with PEMEX's Labor Obligations

The following table show the amounts associated with PEMEX’s labor obligations:

	December 31,
Defined Benefits Liabilities	2017		2016
Liability for defined benefits at retirement and post-employment at the end of the year		Ps. 1,241,072,307		Ps. 1,202,624,665
Liability for other long-term benefits		17,363,815		17,784,771
Total liability for defined benefits recognized in the consolidated statement of financial position at the end of the year		Ps. 1,258,436,122		Ps. 1,220,409,436

Summary of Amounts Recognized for Long-term Obligations

The following tables contain detailed information regarding PEMEX’s retirement and post-employment benefits:

	December 31,
Changes in the liability for defined benefits	2017			2016
Liability for defined benefits at the beginning of the year		Ps. 1,202,624,665			Ps. 1,258,480,019
Recognition of the modifications in pensions plan		8,327			(571,713	)
Current Service cost		13,079,341			23,111,918
Net interest		95,402,917			90,527,624
Past service costs		—			(33,244	)
Defined benefits paid by the fund		(5,105,669	)		(4,892,767	)
Actuarial (gains) losses in other comprehensive results due to:
Change in financial assumptions		47,182,448			(149,533,263	)
Change in demographic assumptions		(70,012,604	)		4,842,109
For experience during the year		10,272,231			36,103,857
In plan assets during the year		(453,206	)		285,123
Remeasurements		26,417			(1,742	)
Contributions paid to the fund		(51,952,560	)		(55,693,256	)
Defined benefit liabilities at end of year		Ps. 1,241,072,307			Ps. 1,202,624,665

In 2017 and 2016, the net actuarial gains recognized in other comprehensive income (loss) net of income deferred tax were Ps. (12,038,710) and Ps. (106,387,640), respectively, related to retirement and post-employment benefits, not including the normal year to year increase in obligations based on changes in population, age, seniority, wages, pensions and benefits. The decrease in losses in 2017 was mainly due to the decrease in the discount and return on plan assets rates, from 8.17% in 2016 to 7.89% in 2017.

	December 31,
Changes in pension plan assets	2017			2016
Plan assets at the beginning of year	Ps.	9,489,666		Ps.	5,228,909
Return on plan assets		902,550			742,477
Payments by the pension fund		(54,312,270	)		(51,889,821	)
Company contributions to the fund(1)		51,952,559			55,693,256
Actuarial (gains) losses in plan assets		453,187			(285,155	)
Pension plan assets at the end of year	Ps.	8,485,692		Ps.	9,489,666

⁽¹⁾  Includes proceeds from the collected amounts of the Promissory Notes, contributed by the Mexican Government (See Note 14).

Summary of Amounts and Types of Plan Assets

As of December 31, 2017 and 2016, the amounts and types of plan assets are as follows:

	December 31,
Plan Assets	2017		2016
Cash and cash equivalents	Ps.	135,757	Ps.	5,906,660
Equity instruments		1,034,178		2,694,291
Debt instruments		7,315,757		888,715
Total plan assets	Ps.	8,485,692	Ps.	9,489,666

	December 31,
Changes in Defined Benefit Obligations (DBO)	2017			2016
Defined benefit obligations at the beginning of the year	Ps.	1,212,114,331		Ps.	1,263,708,928
Service costs		19,762,661			23,107,851
Financing costs		96,331,015			91,270,383
Past service costs					(33,244	)
Payments by the fund		(59,417,940	)		(56,778,359	)
Amount of (gains) and losses recognized through other comprehensive income:		(12,594,541	)		(108,589,515	)
Modifications to the pension plan		(6,609,657	)		(571,713	)
Remeasurements		(1,471	)		—
Reductions		(26,399	)		—
Defined benefit obligations at the end of year	Ps.	1,249,557,999		Ps.	1,212,114,331

Summary of Additional Fair value Disclosure About Plan Assets and Indicate Their Rank

The following tables present additional fair value disclosure about plan assets and indicate their rank, in accordance with IFRS 13, as of December 31, 2017 and 2016:

	Fair value measurements as of December 31, 2017
Plan assets	Quoted prices in active markets for identical assets (level 1)		Significant observable inputs (level 2)		Significant unobservable inputs (level 3)		Total
Cash and cash equivalents	Ps.	135,757	Ps.	—	Ps.	—	Ps.	135,757
Equity instruments		1,034,178		—		—		1,034,178
Debt instruments		7,315,757		—		—		7,315,757
Total	Ps.	8,485,692	Ps.	—	Ps.	—	Ps.	8,485,692

	Fair value measurements as of December 31, 2016
Plan assets:	Quoted prices in active markets for identical assets (level 1)		Significant observable inputs (level 2)		Significant unobservable inputs (level 3)		Total
Cash and cash equivalents	Ps.	5,906,660	Ps.	—	Ps.	—	Ps.	5,906,660
Equity instruments		2,694,291		—		—		2,694,291
Debt instruments		888,715		—		—		888,715
Total	Ps.	9,489,666	Ps.	—	Ps.	—	Ps.	9,489,666

Summary of Principal Actuarial Assumptions Used in Determining the Defined Benefit Obligation

The principal actuarial assumptions used in determining the defined benefit obligation for the plans are as follows:

	December 31,
	2017			2016
Rate of increase in salaries		4.77	%		4.77	%
Inflation assumption		3.75	%		3.75	%
Discount and return on plan assets rate		7.89	%		8.17	%
Average length of obligation (years)		18.40			17.67

Actuarial assumption of expected rates of salary increases [member]

Summary of Principal Actuarial Assumptions Used in Determining the Defined Benefit Obligation

As of December 31, 2017 and 2016, the principal actuarial assumptions used in determining the defined benefit obligation for the plans are as follows:

	December 31,
	2017			2016
Rate of increase in salaries		4.77	%		4.77	%
Rate of increase in pensions		3.75	%		3.75	%
Rate of increase in medical services		7.65	%		7.65	%
Inflation assumption		3.75	%		3.75	%
Discount and return on plan assets rate		7.89	%		8.17	%
Average length of obligation (years)		18.40			17.67

Other Long-term Benefits [member]

Summary of Amounts Recognized for Long-term Obligations

The amounts recognized for long-term obligations for the years ended December 31, 2017 and 2016 are as follows:

	December 31,
Change in the liability for defined benefits	2017			2016
Liabilities defined benefit at the beginning of year	Ps.	17,784,771		Ps.	20,905,422
Charge to income for the year		3,277,847			3,420,158
Actuarial (gains) losses recognized in income due to:
Change in financial assumptions		878,516			(3,028,211	)
Change in demographic assumptions		(1,015,274	)		(119,982	)
For experience during the year		(3,558,599	)		(3,390,396	)
Benefits paid		(3,446	)		(2,220	)
Liabilities defined benefit at the end of year	Ps.	17,363,815		Ps.	17,784,771

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Provisions for Sundry Creditors (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Summary of Provisions for Sundry Creditors and Others

At December 31, 2017 and 2016, the provisions for sundry creditors and others is as follows:

	2017		2016
Provision for plugging of wells (Note 12)	Ps.	68,797,600	Ps.	64,967,710
Provision for trails in process (Note 25)		7,812,689		15,119,692
Provision for environmental costs		11,067,134		8,230,476
	Ps.	87,677,423	Ps.	88,317,878

Summary of Allowance Account for Plugging of Wells, Trials in Progress and Environmental Costs

The following tables show the allowance account for plugging of wells, trials in progress and environmental costs:

	Plugging of wells
	2017			2016
Balance at the beginning of the year	Ps.	64,967,710		Ps.	56,894,695
Decrease capitalized in fixed assets		(3,791,482	)		(3,878,503	)
Unwinding of discount against income		7,774,000			11,968,966
Amount used		(152,628	)		(17,448	)
Balance at the end of the year	Ps.	68,797,600		Ps.	64,967,710

	Trials in progress
	2017			2016
Balance at the beginning of the year	Ps.	15,119,692		Ps.	12,775,263
Additions against income		2,835,357			3,049,202
Provision cancellation		(1,973,153	)		(632,806	)
Amount used		(8,169,207	)		(71,967	)
Balance at the end of the year	Ps.	7,812,689		Ps.	15,119,692

	Environmental costs
	2017			2016
Balance at the beginning of the year	Ps.	8,230,476		Ps.	3,521,838
Additions against income		3,203,982			6,118,454
Provision cancellation		(312,937	)		(1,347,285	)
Amount used		(54,387	)		(62,531	)
Balance at the end of the year(1)	Ps.	11,067,134		Ps.	8,230,476

(1) PEMEX is subject to the provisions of the Ley General del Equilibrio Ecológico y la Protección al Ambiente (General Law on Ecological Equilibrium and Environmental Protection). To comply with this law, environmental audits of PEMEX’s larger operating, storage and transportation facilities have been or are being conducted. Following the completion of such audits, PEMEX has signed various agreements with the Procuraduría Federal de Protección al Ambiente (Federal Attorney of Environmental Protection) to implement environmental remediation and improve environmental plans. Such plans contemplate remediation for environmental damages, as well as related investments for the improvement of equipment, maintenance, labor and materials.

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Disclosures of Cash Flow (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Summary of Non-cash Transactions and are Presented for Disclosure Purposes

The following items represent non-cash transactions and are presented for disclosure purposes:

	For the years ended December 31,
	2017			2016		2015
Operating activities
Employee benefits equity effect(i)		Ps. 12,038,710			Ps. 106,277,761		Ps. 78,556,569
Net (benefits) cost of the year for employee benefits(i)		108,073,074			109,738,416		(62,549,142	)
Investing activities(ii)
Available-for-sale financial assets		5,564,130			207,817		(3,206,316	)
Financing activities
Financed Public Works Contracts		—			146,217,292		2,001,093
Currency translation effect		(7,597,283	)		21,386,902		13,262,101
Accrued interest		8,734,131			9,326,945		4,816,784

(i) Items that do not impact cash flows but that reflect the actuarial valuation at the end of the year.

(ii) Non-cash investing transactions are included in Note 12-d.

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Income Taxes and Federal Duties (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Summary of Total DUC and Others

Total DUC and other as of December 31, 2017 and 2016 are integrated as follows:

	2017			2016
DUC	Ps.	372,902,629		Ps.	304,299,019
DUC from prior years		2,095,429			—
Other		260,775			514,356
Deferred DUC benefit		(37,214,624	)		(27,651,571	)
Total DUC and other	Ps.	338,044,209		Ps.	277,161,804

Summary of Principal Factors Generating the Deferred DUC

The principal factors generating the deferred DUC are the following:

	2017			2016
Deferred DUC asset:
Provisions	Ps.	541,360,940		Ps.	570,544,863
Total deferred DUC asset		541,360,940			570,544,863
Deferred Profit-sharing duty liability:
Wells, pipelines, properties, plant and equipment		(455,697,786	)		(473,406,721	)
Deferred DUC liability		(455,697,786	)		(473,406,721	)
Deferred asset net		85,663,154			97,138,142
Valuation reserve(1)		(20,796,959	)		(69,486,571	)
Net, deferred DUC asset	Ps.	64,866,195		Ps.	27,651,571
(1)   PEMEX added to its valuation reserve since it estimates that some allowed deductions will not materialize in future years.

Summary of Expected Benefit for DUC

The expected expense for DUC is different from that which would result from applying the 65% rate to the tax base, as a result of the items mentioned below:

	2017			2016
Expected expense:		Ps. 127,436,912			Ps. 159,897,683
Increase (decrease) resulting from:
Non-cumulative profit		(514,780,219	)		(423,761,673	)
Non-deductible expenses		387,343,306			263,863,990
Production value		518,433,469			441,655,000
Deductible duties		(39,503,110	)		(29,918,201	)
Deferred DUC reserve		(48,689,612	)		69,486,571
Deductions cap		(94,552,741	)		(204,575,922	)
DUC from prior years		2,095,429			—
Other		260,775			514,356
DUC-Profit-sharing duty expense		Ps. 338,044,209			Ps. 277,161,804

Summary of Income Tax Expense (Benefit)

For the years ended December 31, 2017, 2016 and 2015, Petroleos Mexicanos and its Subsidiary Companies incurred the following income tax expense (benefit):

	2017			2016			2015
Current income tax	Ps.	3,546,912		Ps.	6,201,842		Ps.	7,426,892
Deferred income tax		(9,334,064	)		(18,842,211	)		(53,014,159	)
Total	Ps.	(5,787,152	)	Ps.	(12,640,369	)	Ps.	(45,587,267	)
Income tax REFIPRE (Preferent Fiscal Regime)	Ps.	722,984		Ps.	—		Ps.	—

Summary of Principal Factors Generating Deferred Income Tax

The principal factors generating the deferred income tax are the following:

	2016			Recognized in profit and loss			Recognized in OCI			2017
Deferred income tax asset:
Provisions	Ps.	5,906,581		Ps.	2,393,237		Ps.	—		Ps.	8,299,818
Employee benefits provision		125,973,332			4,902,275			(800,284	)		130,075,323
Advance payments from clients		1,046,010			1,728,296			—			2,774,306
Accrued liabilities		2,269,561			(1,897,574	)		—			371,987
Non-recoverable accounts receivable		778,179			(38,431	)		—			739,748
Derivative financial instruments		223,518			(144,263	)		—			79,255
Wells, pipelines, properties and equipment		458,273,897			(52,834,079	)		—			405,439,818
Tax loss carryforwards(1)		43,327,737			(9,216,777	)		—			34,110,960
Total deferred income tax asset		637,798,815			(55,107,316	)		(800,284	)		581,891,215
Valuation reserve(2)		(565,125,697	)		64,560,772			—			(500,564,925	)
Net deferred income tax asset		72,673,118			9,453,456			(800,284	)		81,326,290
Deferred income tax liability:
Wells, pipelines, properties, plant and equipment		(3,632,294	)		188,676			—			(3,443,618	)
Other		(502,242	)		(308,068	)		—			(810,310	)
Total deferred income tax liability		(4,134,536	)		(119,392	)		—			(4,253,928	)
Net long-term deferred income tax liability	Ps.	68,538,582		Ps.	9,334,064		Ps.	(800,284	)	Ps.	77,072,362

	2015			Recognized in profit and loss			Recognized in OCI and equity (3)			2016
Deferred income tax asset:
Provisions	Ps.	25,414,822		Ps.	(19,508,241	)	Ps.	—		Ps.	5,906,581
Employee benefits provision		247,834,882			(119,837,137	)		(2,024,413	)		125,973,332
Advance payments from clients		1,015,357			30,653			—			1,046,010
Accrued liabilities		1,514			2,268,047			—			2,269,561
Non-recoverable accounts receivable		104,346			673,833			—			778,179
Derivative financial instruments		22,506			201,012			—			223,518
Wells, pipelines, properties and equipment		446,970,333			11,303,564			—			458,273,897
Tax loss carryforwards(1)		14,894,231			28,433,506			—			43,327,737
Total deferred income tax asset		736,257,991			(96,434,763	)		(2,024,413	)		637,798,815
Valuation reserve(2)		(681,357,607	)		116,231,910			—			(565,125,697	)
Net deferred income tax asset		54,900,384			19,797,147			(2,024,413	)		72,673,118
Deferred income tax liability:
Wells, pipelines, properties, plant and equipment		(1,909,529	)		(726,999	)		(995,766	)		(3,632,294	)
Other		(274,305	)		(227,937	)		—			(502,242	)
Total deferred income tax liability		(2,183,834	)		(954,936	)		(995,766	)		(4,134,536	)
Net long-term deferred income tax liability	Ps.	52,716,550		Ps.	18,842,211		Ps.	(3,020,179	)	Ps.	68,538,582

(1) Tax loss carryforwards expire in 2027.

(2) Due to PEMEX’s estimate that not enough taxable income will be generated in future periods, a valuation reserve was recognized to account for the deferred income tax asset.

(3) Includes effects from business combination in equity of Ps. (995,766).

Summary of Expense (Benefit) Attributable to Profit (Loss) from Continuing Operations before Income Taxes

Expense attributable to the profit (loss) from continuing operations before income taxes was different from that which would result from applying the 30% rate to profit, as a result of the items listed below:

	For the years ended December 31,
	2017			2016			2015
Expected income tax expense	Ps.	(20,055,588	)	Ps.	(14,901,324	)	Ps.	(3,089,241	)
Increase (decrease) resulting from:
Tax effect of inflation-net		14,302,118			8,098,213			(1,618,327	)
Difference between accounting and tax depreciation		(3,713,920	)		(1,765,183	)		(107,231	)
Non-deductible expenses		1,954,659			1,558,120			(1,921,515	)
Others-net		(1,725,579	)		(5,630,195	)		(38,850,953	)
Income tax expense	Ps.	(5,787,152	)	Ps.	(12,640,369	)	Ps.	(45,587,267	)

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Equity (Deficit), Net (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Summary of Permanent Equity

PEMEX’s permanent equity is as follows:

	Amount
Certificates of Contribution “A” as of December 31, 2015	Ps.	194,604,835
Increase in Certificates of Contribution “A” during 2016		161,939,612
Certificates of Contribution “A” as of December 31, 2016		356,544,447
Increase in Certificates of Contribution “A” during 2017		—
Certificates of Contribution “A” as of December 31, 2017	Ps.	356,544,447

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Oher Revenues and Expenses - Net (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Summary of Other Revenues and Expenses, net

Other revenues and expenses-net for each of the years ended December 31, 2017, 2016 and 2015, was as follows:

	2017			2016			2015
Revenues:
Claims recovery	Ps.	16,386,250		Ps.	3,695,217		Ps.	1,975,281
Fiscal support (Profit-sharing duty) (see Note 20a.)		—			28,439,379			—
Other income for services		4,720,546			4,266,854			3,953,888
Price of sale share (see Note 11-iii)		3,139,103			22,684,736			—
Other		4,277,207			14,228,801			6,992,954
Revenues from reinsurance premiums		1,986,568			3,694,026			1,497,779
Franchise fees		917,934			1,059,333			1,148,528
Bidding terms, sanctions, penalties and other		825,956			3,223,437			1,262,458
Gain on sale of fixed assets		—			2,687,652			—
Assets value transferred to CENAGAS		—			7,450,931			—
Negative IEPS		—			—			2,519,126
Total other revenues		32,253,564			91,430,366			19,350,014
Expenses:
Loss in the Assets value transferred to CENAGAS		—			(35,333,411	)		—
Disposal of assets		(8,447,031	)		(2,140,943	)		(3,364,063	)
Transportation and distribution of natural gas		(6,652,878	)		(8,830,967	)		(369,317	)
Other		(7,927,150	)		(3,581,036	)		(726,589	)
Claims		(3,640,036	)		(4,757,116	)		(12,527,548	)
Loss in the sale of associates		(412,393	)		(7,473,698	)		—
Impairment of goodwill		—			(4,007,018	)		—
Services provided		—			(2,656,571	)		(3,237,984	)
Total other expenses		(27,079,488	)		(68,780,760	)		(20,225,501	)
Other revenues and expenses-net	Ps.	5,174,076		Ps.	22,649,606		Ps.	(875,487	)

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Related Parties (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Summary of Ownership Interests

Company	Name	Ownership share
Servicio Cozumel, S. A. de C. V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1)		60	%
	Mr. Pedro Oscar Joaquín Delbouis (son of Mr. Joaquín Coldwell)		20	%
	Mr. Nassim Joaquín Delbouis (son of Mr. Joaquín Coldwell)		20	%
Planta de Combustible Cozumel, S. A. de C. V. (which operates as a wholesale distributor)	Fideicomiso Testamentario(2)		57	%
	Mr. Pedro Joaquín Coldwell(1)		40	%
Gasolinera y Servicios Juárez, S. A. de C. V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1)		40	%
	Fideicomiso Testamentario(3)		40	%
	Mr. Ignacio Nassim Ruiz Joaquín (nephew of Mr. Joaquín Coldwell)		20	%
Combustibles Caleta, S. A. de C. V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1)		20	%
	Mr. Pedro Oscar Joaquín Delbouis		20	%
	Mr. Nassim Joaquín Delbouis		20	%
	Fideicomiso Testamentario(4)		20	%
	Mr. Ignacio Nassim Ruiz Joaquín		20	%
Combustibles San Miguel, S. A. de C. V. (which operates a retail service station)	Mr. Pedro Joaquín Coldwell(1)		25	%
	Mr. Pedro Oscar Joaquín Delbouis		25	%
	Mr. Nassim Joaquín Delbouis		25	%
	Mr. Ignacio Nassim Ruiz Joaquín		25	%

(1) In November, 2017, Mr. Pedro Joaquín Coldwell transmitted all of his shares in these companies to a management and investment trust held at Banco Mercantil del Norte, S.A., Institución de Banca Múltiple, Grupo Financiero Banorte.

(2) 60% of these shares were owned by Fausto Nassim Joaquín Ibarra (father of Pedro Joaquín Coldwell), until his death in June of 2016, after which 57% of these shares became property of an investment, management and testamentary revocable trust, which is referred to as the Testamentary Trust. 50% of the voting rights of these shares are currently exercised by Mr. Pedro Oscar Joaquín Delbouis, and 50% are exercised by Mr. Nassim Joaquín Delbouis.

(3) 40% of these shares were owned by Fausto Nassim Joaquín Ibarra until his death in June of 2016, after which these shares became property of the Testamentary Trust. 100% of the voting rights of these shares are currently exercised by Mr. Pedro Joaquín Coldwell.

(4) 20% of these shares were owned by Fausto Nassim Joaquín Ibarra until his death in June of 2016, after which these shares became property of the Testamentary Trust. 50% of the voting rights of these shares are currently exercised by Mr. Pedro Oscar Joaquín Delbouis, and 50% are exercised by Mr. Nassim Joaquín Delbouis.

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Commitments (Tables)

12 Months Ended

Dec. 31, 2017

Estimated Future Payments Under Contract

Estimated future payments under this contract for upcoming fiscal years are as follows:

2018	Ps.	773,047
2019		783,197
2020		785,670
2021		786,323
2022		782,584
2023 and thereafter		3,595,798
Total	Ps.	7,506,619

Estimated Value of Contracts

As of December 31, 2017 and 2016, the estimated value of these contracts was as follows:

Maturity	2017		2016
Up to 1 year	Ps.	5,533,174	Ps.	7,366,247
1 to 3 years		1,891,557		2,518,207
4 to 5 years		1,856,006		2,470,878
More than 5 years		3,123,173		4,157,843
Total	Ps.	12,403,910	Ps.	16,513,175

Development Expenditure [member]

Estimated Value of Contracts

e. As of December 31, 2017 and 2016, the estimated value of the contracts that PEMEX has entered into with several contractors for the development of various infrastructure and services works was as follows:

Maturity	2017		2016
Up to 1 year	Ps.	229,738,368	Ps.	347,606,848
1 to 3 years		196,335,411		281,563,607
4 to 5 years		123,159,215		69,541,826
More than 5 years		149,672,236		119,281,849
Total	Ps.	698,905,230	Ps.	817,994,130

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Business Combination (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Net Fair Value of Assets and Liabilities at Acquisition Date

The net fair value of Fertinal’s assets and liabilities as of the date of acquisition is:

	Fair value
Cash and cash equivalents	Ps.	(6,943	)
Accounts receivable		102,121
Inventories		762,254
Properties, plant and equipment		9,811,928
Other assets		1,671,718
Total assets		12,341,078
Accounts payable	Ps.	2,331,540
Debt		9,365,152
Deferred taxes		328,578
Total liabilities		12,025,270
Total assets, net	Ps.	315,808
Transaction value	Ps.	4,322,826
Goodwill	Ps.	4,007,018

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Subsidiary Guarantor Information (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Summary of Principal Amount Outstanding of Registered Debt Securities

The following table sets forth, as of December 31, 2017, the principal amount outstanding of the registered debt securities originally issued by the Master Trust. As noted above, Petróleos Mexicanos has assumed, as primary obligor, all of the obligations of the Master Trust under these debt securities. The obligations of Petróleos Mexicanos are guaranteed by the Subsidiary Guarantors:

Table 1: Registered Debt Securities originally issued by the Master Trust and Assumed by Petróleos Mexicanos

Security	Primary obligor	Guarantors	Principal amount outstanding (U.S. $)
5.75% Guaranteed Notes due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		834,688
6.625% Guaranteed Bonds due 2035	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,750,000
6.625% Guaranteed Bonds due 2038	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		491,175
8.625% Bonds due 2022	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		160,245
8.625% Guaranteed Bonds due 2023	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		106,507
9 1⁄4% Guaranteed Bonds due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		107,109
9.50% Guaranteed Bonds due 2027	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		219,217

The following table sets forth, as of December 31, 2017, the principal amount outstanding of the registered debt securities issued by Petróleos Mexicanos, and guaranteed by Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services.

Table 2: Registered Debt Securities originally issued by Petróleos Mexicanos

Security	Issuer	Guarantors	Principal amount outstanding (U.S. $)
8.00% Notes due 2019	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,312,015
9 1⁄4% Global Guaranteed Bonds due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		9,296
9.50% Global Guaranteed Bonds due 2027	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		102,149
3.500% Notes due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		355,356
Floating Rate Notes due 2018	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		498,570
6.000% Notes due 2020	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		995,364
5.50% Notes due 2021	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,962,047
3.500% Notes due 2023	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,099,730
4.875% Notes due 2024	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,499,136
6.625% Notes due 2035	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		999,000
6.500% Bonds due 2041	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		3,000,000
4.875% Bonds 2022	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,097,055
3.125% Notes due 2019	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		325,778
3.500% Notes due 2020	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,465,367
5.50% Bonds due 2044	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,657,962
6.375% Bonds due en 2045	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,999,980
5.625% Bonds due 2046	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,996,226
4.500% Notes due 2026	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,489,718
4.250% Notes due 2025	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		998,435
5.500% Notes due 2019	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		740,851
6.375% Notes due 2021	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		1,247,668
6.875% Notes due 2026	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,970,334
4.625% Notes due 2023	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		2,055,498
6.750% Notes due 2047	Petróleos Mexicanos	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services		3,671,628

Supplemental Statement of Financial Position

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF FINANCIAL POSITION

As of December 31, 2017

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries		Eliminations			PEMEX consolidated
Assets
Current assets
Cash and cash equivalents	Ps.	46,959,103		Ps.	18,815,345		Ps.	32,077,306	Ps.	—		Ps.	97,851,754
Accounts receivable and other, net, and derivative financial instruments		83,119,394			38,105,354			79,533,940		—			200,758,688
Accounts receivable—inter-company		311,148,593			1,380,100,592			86,354,837		(1,777,604,022	)		—
Inventories		509,375			32,357,125			30,992,430		—			63,858,930
Available-for-sale financial assets		—			—			1,056,918		—			1,056,918
Total current assets		441,736,465			1,469,378,416			230,015,431		(1,777,604,022	)		363,526,290
Long-term receivables—intercompany		1,823,276,758			285			3,597,880		(1,826,874,923	)		—
Investments in joint ventures and associates		(465,832,399	)		82,668			16,611,681		465,845,414			16,707,364
Wells, pipelines, properties, plant and equipment-net		12,444,376			1,370,974,060			53,090,890		—			1,436,509,326
Long-term notes receivables		147,286,367			1,206,542			—		—			148,492,909
Deferred taxes		59,691,528			84,443,897			2,057,060		—			146,192,485
Intangible assets		—			9,088,563			—		—			9,088,563
Other assets		2,209,579			4,846,078			4,429,520		—			11,485,177
Total assets	Ps.	2,020,812,674		Ps.	2,940,020,509		Ps.	309,802,462	Ps.	(3,138,633,531	)	Ps.	2,132,002,114
Liabilities
Current liabilities
Current portion of long-term debt	Ps.	137,947,110		Ps.	5,386,564		Ps.	13,875,793	Ps.	—		Ps.	157,209,467
Accounts payable—inter-company		1,240,490,891			434,556,688			93,140,905		(1,768,188,484	)		—
Other current liabilities		23,435,614			157,589,107			50,892,997		—			231,917,718
Total current liabilities		1,401,873,615			597,532,359			157,909,695		(1,768,188,484	)		389,127,185
Long-term debt		1,824,829,579			40,262,391			15,573,634		—			1,880,665,604
Long-term payables—inter-company		—			1,830,150,615			6,139,845		(1,836,290,460	)		—
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		297,028,436			1,057,191,286			10,341,988		—			1,364,561,710
Total liabilities		3,523,731,630			3,525,136,651			189,965,162		(3,604,478,944	)		3,634,354,499
Equity (deficit), net		(1,502,918,956	)		(585,116,142	)		119,837,300		465,845,413			(1,502,352,385	)
Total liabilities and equity	Ps.	2,020,812,674		Ps.	2,940,020,509		Ps.	309,802,462	Ps.	(3,138,633,531	)	Ps.	2,132,002,114

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF FINANCIAL POSITION

As of December 31, 2016

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries		Eliminations			PEMEX consolidated
Assets
Current assets
Cash and cash equivalents	Ps.	92,503,607		Ps.	9,732,503		Ps.	61,296,403	Ps.	—		Ps.	163,532,513
Accounts receivable and other, net, and derivative financial instruments		6,604,595			75,760,079			55,713,323		—			138,077,997
Accounts receivable—inter-company		440,645,367			1,684,782,235			70,268,246		(2,195,695,848	)		—
Inventories		446,954			29,270,943			16,174,163		—			45,892,060
Available-for-sale financial assets		—			—			2,852,679		—			2,852,679
Held-for-sale non-financial assets		—			7,460,674			—		—			7,460,674
Total current assets		540,200,523			1,807,006,434			206,304,814		(2,195,695,848	)		357,815,923
Available-for-sale financial assets		—			—			6,027,540		—			6,027,540
Long-term receivables—intercompany		1,740,519,399			289			6,384,944		(1,746,904,632	)		—
Investments in joint ventures and associates		(250,108,630	)		396,681			20,327,813		250,121,645			20,737,509
Wells, pipelines, properties, plant and equipment-net		12,596,722			1,595,655,580			59,489,946		—			1,667,742,248
Long-term notes receivables		140,579,974			8,027,628			—		—			148,607,602
Deferred taxes		59,162,878			40,341,615			820,196		—			100,324,689
Restricted cash		—			9,624,804			853,822		—			10,478,626
Intangible assets		—			8,639,242			—		—			8,639,242
Other assets		1,824,104			2,707,788			4,980,753		—			9,512,645
Total assets	Ps.	2,244,774,970		Ps.	3,472,400,061		Ps.	305,189,828	Ps.	(3,692,478,835	)	Ps.	2,329,886,024
Liabilities
Current liabilities
Current portion of long-term debt		157,937,631			7,381,095			10,847,462		—			176,166,188
Accounts payable—inter-company		1,265,244,986			854,106,939			68,510,835		(2,187,862,760	)		—
Other current liabilities		34,913,773			169,182,239			45,927,686		—			250,023,698
Total current liabilities		1,458,096,390			1,030,670,273			125,285,983		(2,187,862,760	)		426,189,886
Long-term debt		1,737,332,174			46,090,919			23,581,449		—			1,807,004,542
Long-term payables—inter-company		—			1,746,433,870			8,303,850		(1,754,737,720	)		—
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		282,902,667			1,035,019,339			11,777,737		—			1,329,699,743
Total liabilities		3,478,331,231			3,858,214,401			168,949,019		(3,942,600,480	)		3,562,894,171
Equity (deficit), net		(1,233,556,261	)		(385,814,340	)		136,240,809		250,121,645			(1,233,008,147	)
Total liabilities and equity	Ps.	2,244,774,970		Ps.	3,472,400,061		Ps.	305,189,828	Ps.	(3,692,478,835	)	Ps.	2,329,886,024

Supplemental Statement of Comprehensive Income

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF COMPREHENSIVE INCOME

For the year ended December 31, 2017

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Net sales	Ps.	—		Ps.	1,713,914,703		Ps.	1,096,752,930		Ps.	(1,424,768,483	)	Ps.	1,385,899,150
Services income		50,399,983			140,934,022			2,646,144			(182,849,580	)		11,130,569
Total sales revenues		50,399,983			1,854,848,725			1,099,399,074			(1,607,618,063	)		1,397,029,719
Impairment of wells, pipelines, properties, plant and equipment		—			145,302,407			6,142,153			—			151,444,560
Cost of sales		2,007,814			1,447,640,131			1,083,297,610			(1,528,740,675	)		1,004,204,880
Gross income		48,392,169			261,906,187			9,959,311			(78,877,388	)		241,380,279
Other revenues (expenses), net		(341,521	)		(12,443,660	)		(4,664,096	)		22,623,353			5,174,076
General expenses:
Transportation, distribution and sale expenses		—			26,136,674			1,297,558			(5,544,562	)		21,889,670
Administrative expenses		59,141,391			105,920,390			5,883,200			(51,005,527	)		119,939,454
Total general expenses		59,141,391			132,057,064			7,180,758			(56,550,089	)		141,829,124
Operating income		(11,090,743	)		117,405,463			(1,885,543	)		296,054			104,725,231
Financing income		143,676,367			134,401,598			3,185,195			(265,097,307	)		16,165,853
Financing cost		(236,929,035	)		(141,900,236	)		(3,616,530	)		264,801,253			(117,644,548	)
Derivative financial instruments income (cost), net		27,670,991			(1,608,039	)		(724,628	)		—			25,338,324
Foreign exchange income , net		6,837,171			15,807,988			538,963			—			23,184,122
Profit (loss) sharing in joint ventures and associates		(211,567,169	)		409,955			(49,515	)		211,567,169			360,440
Income (loss) before taxes, duties and other		(281,402,418	)		124,516,729			(2,552,058	)		211,567,169			52,129,422
Total taxes, duties and other		(557,520	)		331,001,261			2,536,300			—			332,980,041
Net (loss) income for the year		(280,844,898	)		(206,484,532	)		(5,088,358	)		211,567,169			(280,850,619	)
Total other comprehensive result		4,728,640			6,841,586			(63,845	)		—			11,506,381
Total comprehensive result for the year	Ps.	(276,116,258	)	Ps.	(199,642,946	)	Ps.	(5,152,203	)	Ps.	211,567,169		Ps.	(269,344,238	)

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF COMPREHENSIVE INCOME

For the year ended December 31, 2016

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Net sales	Ps.	—		Ps.	1,361,538,624		Ps.	828,143,332		Ps.	(1,124,563,366	)	Ps.	1,065,118,590
Services income		46,330,245			98,959,131			1,970,055			(138,284,789	)		8,974,642
Total sales revenues		46,330,245			1,460,497,755			830,113,387			(1,262,848,155	)		1,074,093,232
(Reversal) impairment of wells, pipelines, properties, plant and equipment		—			(330,037,834	)		(1,276,509	)		—			(331,314,343	)
Cost of sales		1,236,921			1,244,388,072			809,156,778			(1,188,959,550	)		865,822,221
Gross income		45,093,324			546,147,517			22,233,118			(73,888,605	)		539,585,354
Other revenues (expenses), net		(312,611	)		20,713,184			2,915,837			(666,804	)		22,649,606
General expenses:
Transportation, distribution and sale expenses		—			50,948,771			945,489			(26,663,020	)		25,231,240
Administrative expenses		57,437,455			96,884,031			7,050,271			(48,718,224	)		112,653,533
Total general expenses		57,437,455			147,832,802			7,995,760			(75,381,244	)		137,884,773
Operating income		(12,656,742	)		419,027,899			17,153,195			825,835			424,350,187
Financing income		123,266,281			67,542,768			3,526,378			(180,586,172	)		13,749,255
Financing cost		(160,824,632	)		(114,271,762	)		(3,602,868	)		179,854,798			(98,844,464	)
Derivative financial instruments (cost) income, net		(12,052,200	)		3,172			(1,951,959	)		—			(14,000,987	)
Foreign exchange loss, net		(20,531,005	)		(232,714,446	)		(767,292	)		—			(254,012,743	)
Profit (loss) sharing in joint ventures and associates		(117,347,803	)		628,357			1,507,488			117,347,803			2,135,845
Income (loss) before taxes, duties and other		(200,146,101	)		140,215,988			15,864,942			117,442,264			73,377,093
Total taxes, duties and other		(8,834,626	)		266,155,181			7,200,880			—			264,521,435
Net (loss) income for the year		(191,311,475	)		(125,939,193	)		8,664,062			117,442,264			(191,144,342	)
Total other comprehensive result		10,126,560			96,032,433			21,713,488			—			127,872,481
Total comprehensive result for the year	Ps.	(181,184,915	)	Ps.	(29,906,760	)	Ps.	30,377,550		Ps.	117,442,264		Ps.	(63,271,861	)

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF COMPREHENSIVE INCOME

For the year ended December 31, 2015

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Net sales	Ps.	15,556		Ps.	1,523,767,800		Ps.	803,623,324		Ps.	(1,173,956,323	)	Ps.	1,153,450,357
Services income		16,897,139			16,815,589			2,585,617			(27,988,310	)		8,310,035
Total sales revenues		16,912,695			1,540,583,389			806,208,941			(1,201,944,633	)		1,161,760,392
Impairment of wells, pipelines, properties, plant and equipment		—			476,276,159			1,668,531			—			477,944,690
Benefit from change in pension plan					(83,657,496	)		(8,519,593	)		—			(92,177,089	)
Cost of sales		2,695,423			1,280,404,059			791,147,745			(1,182,282,621	)		891,964,606
Gross income		14,217,272			(132,439,333	)		21,912,258			(19,662,012	)		(115,971,815	)
Other (expenses) revenues, net		(19,805	)		(6,073,003	)		3,326,421			1,890,900			(875,487	)
General expenses:
Transportation, distribution and sale expenses		—			32,870,908			2,921,430			(6,863,699	)		28,928,639
Administrative expenses		59,923,878			52,832,029			10,638,127			(10,921,939	)		112,472,095
Benefit from change in pension plan		(46,031,780	)		(50,394,477	)		(7,434,698	)		—			(103,860,955	)
Total general expenses		13,892,098			35,308,460			6,124,859			(17,785,638	)		37,539,779
Operating income		305,369			(173,820,796	)		19,113,820			14,526			(154,387,081	)
Financing income		108,543,665			28,639,034			3,478,434			(125,670,274	)		14,990,859
Financing cost		(85,544,060	)		(104,453,148	)		(3,306,776	)		125,530,391			(67,773,593	)
Derivative financial instruments (cost) income, net		(22,803,663	)		6,463			1,347,323			—			(21,449,877	)
Foreign exchange loss, net		(14,829,436	)		(139,623,910	)		(312,228	)		—			(154,765,574	)
(Loss) profit sharing in joint ventures and associates		(749,963,960	)		198,786			2,119,329			749,963,960			2,318,115
(Loss) income before taxes, duties and other		(764,292,085	)		(389,053,571	)		22,439,902			749,838,603			(381,067,151	)
Total taxes, duties and other		(51,982,560	)		376,649,369			6,833,438			—			331,500,247
Net (loss) income for the year		(712,309,525	)		(765,702,940	)		15,606,464			749,838,603			(712,567,398	)
Total other comprehensive result		10,980,787			56,585,790			21,045,777			—			88,612,354
Total comprehensive result for the year	Ps.	(701,328,738	)	Ps.	(709,117,150	)	Ps.	36,652,241		Ps.	749,838,603		Ps.	(623,955,044)

Supplemental Statement of Cash Flows

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF CASH FLOWS

For the year ended December 31, 2017

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Operating activities:
Net (loss) income for the year	Ps.	(280,844,898	)	Ps.	(206,484,532	)	Ps.	(5,082,639	)	Ps.	211,561,450		Ps.	(280,850,619	)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization		1,155,881			152,607,943			2,940,689			—			156,704,513
Impairment of wells, pipelines, properties, plant and equipment		—			145,302,407			6,142,153			—			151,444,560
Unsuccessful wells		—			6,164,624			—			—			6,164,624
Exploration costs		—			(1,447,761	)		—			—			(1,447,761	)
Disposal of wells, pipelines, properties, plant and equipment		433,391			14,687,229			1,943,051			—			17,063,671
Gain on sale of share in joint ventures and associates		—			(3,139,103	)		—			—			(3,139,103	)
Disposal of held—for—sale current non—financial assets		—			2,808,360			—			—			2,808,360
Dividends		—			—			(180,675	)		—			(180,675	)
Effects of net present value of reserve for well abandonment		—			7,774,000			—			—			7,774,000
Profit (loss) sharing in investments		211,567,169			(409,955	)		49,515			(211,567,169	)		(360,440	)
Decrease on available—for-sale financial assets		—			—			1,360,205			—			1,360,205
Net loss on available-for-sale financial assets		—			—			3,523,748			—			3,523,748
Unrealized foreign exchange loss (gain)		(13,526,153	)		(1,585,910	)		(1,573,376	)		—			(16,685,439	)
Interest expense		100,545,114			15,736,420			1,363,014			—			117,644,548
Funds (used in) from operating activities:
Accounts receivable, accounts payable and derivative financial instruments		(88,496,967	)		(14,214,566	)		(20,789,692	)		—			(123,501,225	)
Inventories		(62,421	)		(3,086,181	)		(14,818,268	)		—			(17,966,870	)
Other assets		(7,091,867	)		(483,389	)		551,233			—			(7,024,023	)
Employee benefits		18,829,768			31,489,785			(254,157	)		—			50,065,396
Inter-company charges and deductions		7,284,124			(114,968,213	)		514,270			107,169,819			—
Cash flows (used in) from operating activities		(50,206,859	)		30,751,158			(24,310,929	)		107,164,100			63,397,470
Investing activities:
Acquisition of wells, pipelines, properties, plant and equipment		(1,436,926	)		(87,274,561	)		(3,147,978	)		—			(91,859,465	)
Resources from sale available-for-sale financial assets		—			—			8,026,836			—			8,026,836
Resources from sale of shares in associates		—			3,863,072			(721,362	)		—			3,141,710
(Increase) decrease due to Inter-company investing		25,611,359			—			—			(25,611,359	)		—
Cash flows used in investing activities		24,174,433			(83,411,489	)		4,157,496			(25,611,359	)		(80,690,919	)
Financing activities:
Loans obtained from financial institutions		401,947,349			—			302,768,119			—			704,715,468
Debt payments, principal only		(327,703,729	)		(7,981,937	)		(306,374,153	)		—			(642,059,819	)
Interest paid		(93,755,698	)		(13,991,633	)		(1,163,086	)		—			(108,910,417	)
Inter-company increase (decrease) financing		—			83,716,743			(2,164,002	)		(81,552,741	)		—
Cash flows provided by financing activities:		(19,512,078	)		61,743,173			(6,933,122	)		(81,552,741	)		(46,254,768	)
Net (decrease) increase in cash and cash equivalents		(45,544,504	)		9,082,842			(27,086,555	)		—			(63,548,217	)
Effects of change in cash value		—			—			(2,132,542	)		—			(2,132,542	)
Cash and cash equivalents at the beginning of the year		92,503,607			9,732,503			61,296,403			—			163,532,513
Cash and cash equivalents at the end of the year	Ps.	46,959,103		Ps.	18,815,345		Ps.	32,077,306		Ps.	—		Ps.	97,851,754

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF CASH FLOWS

For the year ended December 31, 2016

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Operating activities:
Net (loss) income for the year	Ps.	(191,311,476	)	Ps.	(139,410,398	)	Ps.	22,160,755		Ps.	117,416,777		Ps.	(191,144,342	)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization		1,066,033			146,545,307			2,828,151			—			150,439,491
(Reversal) impairment of wells, pipelines, properties, plant and equipment		—			(330,037,834	)		(1,276,509	)		—			(331,314,343	)
Unsuccessful wells		—			29,106,084			—			—			29,106,084
Exploration costs		—			(2,022,826	)		—			—			(2,022,826	)
Disposal of wells, pipelines, properties, plant and equipment		320,599			2,658,625			792,063			—			3,771,287
Loss in sale of fixed assets		—			27,882,480			—			—			27,882,480
Gain on sale of share in joint ventures and associates		—			(15,211,039	)		—			—			(15,211,039	)
Profit (loss) sharing in joint ventures and associates		117,249,643			(628,356	)		(1,507,489	)		(117,249,643	)		(2,135,845	)
Impairment of goodwill		—			—			4,007,018			—			4,007,018
Dividends		—			—			(293,397	)		—			(293,397	)
Effects of net present value of reserve for well abandonment		—			11,968,966			—			—			11,968,966
Unrealized foreign exchange loss (gain)		231,191,646			6,754,046			5,237,072			—			243,182,764
Interest expense		91,044,541			5,687,502			2,112,421			—			98,844,464
Funds (used in) from operating activities:
Accounts receivable, accounts payable and derivative financial instruments		23,636,331			(158,449,370	)		45,028,534			—			(89,784,505	)
Inventories		83,317			3,508,494			(4,950,690	)		—			(1,358,879	)
Other assets		(2,405,412	)		(22,600,504	)		(122,614	)		—			(25,128,530	)
Employee benefits		2,591,000			136,354,337			(91,652,268	)		—			47,293,069
Inter-company charges and deductions		(393,835,932	)		(83,049,125	)		48,435,633			428,449,424			—
Cash flows (used in) from operating activities		(120,369,710	)		(380,943,611	)		30,798,680			428,616,558			(41,898,083	)
Investing activities:
Acquisition of wells, pipelines, properties, plant and equipment		(2,172,586	)		(147,786,686	)		(1,449,208	)		—			(151,408,480	)
Resources from sale on share in associates		—			23,050,344			(365,608	)		—			22,684,736
Proceeds from the sale of fixed assets		—			560,665			—			—			560,665
Business acquisition		—			—			(4,329,769	)		—			(4,329,769	)
(Increase) decrease due to Inter-company investing		(39,612,699	)		—			—			39,612,699			—
Cash flows used in investing activities		(41,785,285	)		(124,175,677	)		(6,144,585	)		39,612,699			(132,492,848	)
Financing activities:
Increase in equity due to Certificates of Contributions “A”		73,500,000			—			—			—			73,500,000
Loans obtained from financial institutions		571,944,209			34,483,348			235,564,210			—			841,991,767
Debt payments, principal only		(372,809,166	)		(6,414,441	)		(235,763,722	)		—			(614,987,329	)
Interest paid		(82,008,347	)		(4,706,946	)		(2,038,848	)		—			(88,754,141	)
Inter-company increase (decrease) financing		—			464,488,030			3,741227			(468,229,257	)		—
Cash flows provided by financing activities:		190,626,696			487,849,991			1,502,867			(468,229,257	)		211,750,297
Net (decrease) increase in cash and cash equivalents		28,471,701			(17,269,297	)		26,156,962			—			37,359,366
Effects of change in cash value		5,570,892			20,371,126			(9,137,751	)		—			16,804,267
Cash and cash equivalents at the beginning of the year		58,461,014			6,630,674			44,277,192			—			109,368,880
Cash and cash equivalents at the end of the year	Ps.	92,503,607		Ps.	9,732,503		Ps.	61,296,403		Ps.	—		Ps.	163,532,513

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION

STATEMENT OF CASH FLOWS

For the year ended December 31, 2015

	Petróleos Mexicanos			Subsidiary guarantors			Non-guarantor subsidiaries			Eliminations			PEMEX consolidated
Operating activities:
Net (loss) income for the year	Ps.	(712,177,124	)	Ps.	(765,702,826	)	Ps.	15,738,868		Ps.	749,573,684		Ps.	(712,567,398	)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization		789,657			164,221,429			2,940,164			—			167,951,250
Impairment of wells, pipelines, properties, plant and equipment		—			476,276,159			1,668,531			—			477,944,690
Unsuccessful wells		—			23,213,519			—			—			23,213,519
Exploration costs		—			(5,698,511	)		—			—			(5,698,511	)
Disposal of wells, pipelines, properties, plant and equipment		180,992			21,945,266			2,512,279			—			24,638,537
Profit (loss) sharing in joint ventures and associates		749,963,958			(198,786	)		(2,119,329	)		(749,963,958	)		(2,318,115	)
Gain on sale of share in joint ventures and associates		—			(337,675	)		(342,955	)		—			(680,630	)
Dividends		—			—			(359,941	)		—			(359,941	)
Effects of net present value of reserve for well abandonment		—			(608,160	)		—			—			(608,160	)
Unrealized foreign exchange loss (gain)		145,971,158			2,996,219			3,708,879			—			152,676,256
Interest expense		63,460,443			3,414,430			898,720			—			67,773,593
Funds provided by (used in) operating activities:
Accounts receivable, accounts payable and derivative financial instruments		(58,554,144	)		119,761,648			(27,777,939	)		—			33,429,565
Inventories		108,568			4,547,843			1,511,317			—			6,167,728
Other assets		(149,819	)		(16,578,827	)		126,281			—			(16,602,365	)
Employee benefits		(10,037,444	)		(94,183,192	)		(11,801,596	)		—			(116,022,232	)
Inter-company charges and deductions		(310,384,820	)		30,044,041			31,975,215			248,365,564			—
Cash flows provided by operating activities		(130,828,575	)		(36,887,423	)		18,678,494			247,975,290			98,937,786
Investing activities:
Acquisition of wells, pipelines, properties, plant and equipment		(1,496,277	)		(239,315,507	)		(12,702,217	)		—			(253,514,001	)
Investments in associates		—			—			(36,214	)		—			(36,214	)
Resources from the sales on share in associates		—			(130,323	)		4,547,461			—			4,417,138
(Increase) decrease due to Inter-company investing		(39,108,879	)		—			—			39,108,879			—
Cash flows used in investing activities		(40,605,156	)		(239,445,830	)		(8,190,970	)		39,108,879			(249,133,077	)
Financing activities:
Increase in equity due to Certificates of Contributions “A”		10,000,000			(1,915,922	)		1,844,394			71,528			10,000,000
Loans obtained from financial institutions		345,383,990			—			33,587,088			—			378,971,078
Debt payments, principal only		(147,927,857	)		(8,081,177	)		(37,609,464	)		—			(193,618,498	)
Interest paid		(58,123,368	)		(3,443,923	)		(1,169,859	)		—			(62,737,150	)
Inter-company increase (decrease) financing		(3,626,448	)		289,859,173			922,972			(287,155,697	)		—
Cash flows provided by financing activities:		145,706,317			276,418,151			(2,424,869	)		(287,084,169	)		132,615,430
Net (decrease) increase in cash and cash equivalents		(25,727,414	)		84,898			8,062,655			—			(17,579,861	)
Effects of change in cash value		11,185,788			1,138,356			(3,363,931	)		—			8,960,213
Cash and cash equivalents at the beginning of the year		73,002,640			5,407,420			39,578,468			—			117,988,528
Cash and cash equivalents at the end of the year	Ps.	58,461,014		Ps.	6,630,674		Ps.	44,277,192		Ps.	—		Ps.	109,368,880

XML

Supplementary Information on Oil and Gas Exploration And Production Activities (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2017

Text block1 [abstract]

Summary of Capitalized Costs for Oil and Gas Producing Activities

a. Capitalized costs for oil and gas producing activities (unaudited):

	As of December 31,
	2017			2016			2015
Proved reserves	Ps.	2,363,336,481		Ps.	2,476,535,503		Ps.	2,102,971,025
Construction in progress		35,381,089			60,720,261			88,706,330
Accumulated depreciation and amortization		(1,444,962,317	)		(1,355,402,150	)		(1,224,690,867	)
Net capitalized costs	Ps.	953,755,253		Ps.	1,181,853,614		Ps.	966,986,487

Summary of Costs Incurred for Oil and Gas Property Exploration and Development Activities

b. Costs incurred for oil and gas property exploration and development activities (unaudited):

	As of December 31,
	2017		2016
Exploration	Ps.	32,480,801	Ps.	41,661,666
Development		53,460,364		113,895,246
Total costs incurred	Ps.	85,941,165	Ps.	155,556,912

Summary of Results of Operations for Oil and Gas Producing Activities

c. Results of operations for oil and gas producing activities (unaudited):

	2017			2016			2015
Revenues from sale of oil and gas	Ps.	762,637,362		Ps.	616,380,608		Ps.	690,591,455
Hydrocarbon duties		375,156,405			304,299,019			376,682,705
Production costs (excluding taxes)		248,957,950			171,194,337			177,774,082
Other costs and expenses		(3,954,222	)		61,359,271			20,360,540
Exploration expenses		14,993,433			39,693,273			31,244,564
Depreciation, depletion, amortization and accretion		240,672,906			(150,891,739	)		527,014,056
		875,826,472			425,654,161			1,133,075,947
Results of operations for oil and gas producing activities	Ps.	(113,189,111	)	Ps.	190,726,447		Ps.	(442,484,491	)

Summary of Results of Operations for Oil and Gas Producing Activities

d. Sales prices (unaudited)

The following table summarizes average sales prices in U.S. dollars for each of the years ended December 31 (excluding production taxes):

	2017		2016		2015
Weighted average sales price per barrel of oil equivalent (boe)(1)	US$	38.63	US$	29.18	US$	37.17
Crude oil, per barrel		48.71		36.55		48.22
Natural gas, per thousand cubic feet		4.32		3.01		3.78

(1) To convert dry gas to barrels of oil equivalent, a factor of 5.201 thousand cubic feet of dry gas per barrel of oil equivalent is used.

Summary of Oil and Gas Proved Reserves

Summary of oil and gas⁽¹⁾ proved reserves as of December 31, 2017

based on average fiscal year prices

	Crude oil and Condensates(2)		Dry Gas(3)
	(in millions of barrels)		(in billions of cubic feet)
Proved developed and un-developed reserves:
Proved developed reserves		4,166		4,026
Proved undeveloped reserves		2,261		2,567
Total proved reserves		6,427		6,593

Note: Numbers may not total due to rounding.

(1) PEMEX does not currently produce synthetic oil or synthetic gas, or other natural resources from which synthetic oil or synthetic gas can be produced.

(2) Crude oil and condensate reserves include the fraction of liquefiable hydrocarbons recoverable in natural gas processing plants located at fields.

(3) Reserve volumes reported in this table are volumes of dry gas, although natural gas production reported in other tables refers to sour wet gas. There is a shrinkage in volume when natural gas liquids and impurities are extracted to obtain dry gas. Therefore, reported natural gas volumes are greater than dry gas volumes.

Disclosure of Proved Developed and Undeveloped Reserve

Crude oil and condensate reserves

(including natural gas liquids)⁽¹⁾

	2017			2016			2015
	(in millions of barrels)
Proved developed and undeveloped reserves:
At December 31		7,219			7,977			10,292
Revisions(2)		(95	)		189			(1,491	)
Extensions and discoveries		147			(55	)		111
Production		(805	)		(891	)		(935	)
Farm outs & transfer of fields due to NHC bidding process		(38	)		—			—
At December 31		6,427			7,219			7,977
Proved developed reserves at December 31		4,166			4,886			5,725
Proved undeveloped reserves at December 31		2,261			2,333			2,252

Note: Numbers may not total due to rounding.

(1) Crude oil and condensate reserves include the fraction of liquefiable hydrocarbons recoverable in natural gas processing plants located at fields.

(2) Revisions include positive and negative changes due to new data from well drilling, revisions made when actual reservoir performance differs from expected performance and changes in hydrocarbon prices.

Source: Pemex Exploration and Production.

Dry gas reserves

	2017			2016			2015
	(in billions of cubic feet)
Proved developed and undeveloped reserves:
At December 31		6,984			8,610			10,859
Revisions(1)		169			(183	)		(955	)
Extensions and discoveries		468			(308	)		47
Production(2)		(999	)		(1,134	)		(1,341	)
Farm outs & transfer of fields due to NHC bidding process		(29	)		—			—
At December 31		6,593			6,984			8,610
Proved developed reserves at December 31		4,026			4,513			6,012
Proved undeveloped reserves at December 31		2,567			2,471			2,598

Note: Numbers may not total due to rounding.

(1) Revisions include positive and negative changes due to new data from well drilling, revisions made when actual reservoir performance differs from expected performance and changes in hydrocarbon prices.

(2) Production refers here to dry gas, although natural gas production reported in other tables refers to sour wet gas. There is a shrinkage in volume when natural gas liquids and impurities are extracted to obtain dry gas. Therefore, reported natural gas volumes are greater than dry gas volumes.

Disclosure of standardized measure of discounted future net cash flows

Standardized measure of discounted future net cash flows as of December 31

	2017			2016			2015
	(in millions of U.S. dollars)
Future cash inflows	US$	269,489		US$	228,196		US$	325,052
Future production costs (excluding profit taxes)		(114,369	)		(87,942	)		(99,948	)
Future development costs		(26,229	)		(25,515	)		(32,560	)
Future cash flows before tax		128,891			114,738			192,544
Future production and excess gains taxes		(129,377	)		(108,960	)		(167,056	)
Future net cash flows		(487	)		5,779			25,488
Effect of discounting net cash flows by 10%		(4,600	)		(937	)		(9,946	)
Standardized measure of discounted future net cash flows	US$	4,113		US$	4,841		US$	15,541

Note: Table amounts may not total due to rounding.

Disclosure of Changes in Standardized Measure of Discounted Future Net Cash Flows

Changes in standardized measure of discounted future net cash flows

	2017			2016			2015
	(in millions of U.S. dollars)
Sales of oil and gas produced, net of production costs	US$	(25,076	)	US$	(19,411	)	US$	(28,371	)
Net changes in prices and production costs		26,355			(53,278	)		(327,865	)
Extensions and discoveries		3,639			1,105			3,086
Development cost incurred during the year		2,699			4,124			10,172
Changes in estimated development costs		2,744			1,763			(2,171	)
Reserves revisions and timing changes		(1,353	)		6,366			(22,801	)
Accretion of discount of pre-tax net cash flows		5,891			11,094			43,394
Net changes in production and excess gains taxes		(15,628	)		37,537			295,437
Aggregate change in standardized measure of discounted future net cash flows	US$	(728	)	US$	(10,700	)	US$	(29,119	)
Standardized measure:
As of January 1	US$	4,841		US$	15,541		US$	44,661
As of December 31		4,113			4,841			15,541
Change	US$	(728	)	US$	(10,700	)	US$	(29,119	)

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Structure and Business Operations of Petroleos Mexicanos, Subsidiary Entities and Subsidiary Companies - Additional Information (Detail)	Dec. 31, 2017
Description of business and nature of operations [abstract]
Ownership percentage	100.00%

XML

Basis of Preparation - Additional Information (Detail) $ in Thousands, $ in Thousands				12 Months Ended
	Nov. 03, 2017 bbl	Oct. 05, 2017	Jul. 06, 2017	Dec. 31, 2017 USD ($) Exchange_Rate	Dec. 31, 2017 MXN ($) Exchange_Rate	Dec. 31, 2016 MXN ($) Exchange_Rate	Dec. 31, 2015 MXN ($) Exchange_Rate	Dec. 31, 2017 MXN ($)	Nov. 17, 2016 USD ($)	Nov. 17, 2016 MXN ($)	Nov. 18, 2015 USD ($)	Nov. 18, 2015 MXN ($)
Disclosure of basis of preparation of financial statements [line items]
Unrecognized net losses						$ 191,144,342		$ 280,850,619
Negative equity amount						1,233,008,147		1,502,352,385
Working capital decreasing amount					$ 25,600,895	68,373,963
Net cash flows (used in) from operating activities				$ 3,204,044	$ 63,397,470	$ (41,898,083)	$ 98,937,786
Estimated reserve of oil equivalent | bbl	1,500,000,000
Percentage of volume available placed at market price			100.00%
Estimated maximum borrowings permissible under statute									$ 8,055,900	$ 150,000,000	$ 15,722,000	$ 240,550,000
Amount available under lines of credit				$ 6,700,000				23,500,000
Percentage of increase in annual budget				1.70%	1.70%
Employee benefits provision				35.00%	35.00%	34.00%
Bottom of range [member]
Disclosure of basis of preparation of financial statements [line items]
Market share percentage				65.00%	65.00%
Internal debt [member]
Disclosure of basis of preparation of financial statements [line items]
Estimated maximum borrowings permissible under statute								30,000,000
External debt [member]
Disclosure of basis of preparation of financial statements [line items]
Estimated maximum borrowings permissible under statute				$ 6,182,800
Pemex industrial transformation [member]
Disclosure of basis of preparation of financial statements [line items]
Percentage of interest held		50.00%
Foreign exchange rate | Exchange_Rate						20.6640	17.2065
Pemex Industrial Transformation TAG Norte Holding [member]
Disclosure of basis of preparation of financial statements [line items]
Percentage of indirect interest held		5.00%
Pemex exploration and production [member]
Disclosure of basis of preparation of financial statements [line items]
Foreign exchange rate | Exchange_Rate				19.7867	19.7867	20.6640	17.2065
3P reserves [member]
Disclosure of basis of preparation of financial statements [line items]
Estimated reserve of oil equivalent | bbl	350,000,000
2016 [member]
Disclosure of basis of preparation of financial statements [line items]
Indebtedness amount								231,618,067
Annual budget amount					$ 385,211,257
2017 [member]
Disclosure of basis of preparation of financial statements [line items]
Indebtedness amount								$ 72,412,672
Annual budget amount					$ 391,946,000

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Significant Accounting Policies - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2017
Disclosure of significant accounting policies [line items]
Description of voting right	PEMEX owns directly or indirectly between 20% and 50% of voting rights in another entity.
Cash and cash equivalents maturity period	Three months or less
Bottom of range [member]
Disclosure of significant accounting policies [line items]
Voting rights in another entity	20.00%
Expected percentage of increase in accounts receivable reserves	39.00%
Top of range [member]
Disclosure of significant accounting policies [line items]
Voting rights in another entity	50.00%
Expected percentage of increase in accounts receivable reserves	51.10%

XML

Significant Accounting Policies - Disclosure of Consolidated Statements of Financial Position (Detail) $ in Thousands, $ in Thousands	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure of reclassification of financial assets [line items]
Available-for-sale financial assets	$ 53,416	$ 1,056,918	$ 2,852,679
Total current assets	18,372,255	363,526,290	357,815,923	$ 267,200,497
Investments in joint ventures and associates	844,373	16,707,364	20,737,509	$ 24,165,599
Total non-current assets	$ 89,376,997	$ 1,768,475,824	1,972,070,101
As previously reported [member]
Disclosure of reclassification of financial assets [line items]
Available-for-sale financial assets			435,556
Total current assets			355,398,800
Investments in joint ventures and associates			23,154,632
Total non-current assets			1,974,487,224
Reclassification [member]
Disclosure of reclassification of financial assets [line items]
Available-for-sale financial assets			2,417,123
Total current assets			2,417,123
Investments in joint ventures and associates			(2,417,123)
Total non-current assets			$ (2,417,123)

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Significant Accounting Policies - Summary of Reclassification of Other Income (Expenses) (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure of significant accounting policies [line items]
Services income	$ 562,528	$ 11,130,569	$ 8,974,642	$ 8,310,035
Total of sales	70,604,483	1,397,029,719	1,074,093,232	1,161,760,392
Cost of sales	50,751,509	1,004,204,880	865,822,221	891,964,606
Gross income (loss)	12,199,118	241,380,279	539,585,354	(115,971,815)
Other income (expenses), net	$ 261,493	$ 5,174,076	22,649,606	(875,487)
As previously reported [member]
Disclosure of significant accounting policies [line items]
Services income			14,427,081	12,912,112
Total of sales			1,079,545,671	1,166,362,469
Cost of sales			867,580,634	895,068,904
Gross income (loss)			543,279,380	(114,474,036)
Other income (expenses), net			18,955,580	(2,373,266)
Reclassification [member]
Disclosure of significant accounting policies [line items]
Services income			(5,452,439)	(4,602,077)
Total of sales			(5,452,439)	(4,602,077)
Cost of sales			(1,758,413)	(3,104,298)
Gross income (loss)			(3,694,026)	(1,497,779)
Other income (expenses), net			$ 3,694,026	$ 1,497,779

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Significant Accounting Policies - Summary of Better Presentation in Duties, Taxes and Other, Certain Amounts in Income Tax (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2016 MXN ($)
Hydrocarbon Extraction Duties And Others [Member]
Disclosure of significant accounting policies [line items]
As previously reported	$ 304,813,375
Reclassification	(27,651,571)
Following reclassification	277,161,804
Income Taxes [Member]
Disclosure of significant accounting policies [line items]
As previously reported	(40,291,940)
Reclassification	27,651,571
Following reclassification	$ (12,640,369)

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Segment Financial Information - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2017 Segment Major_Customer
Disclosure of operating segments [abstract]
Number of business segments | Segment	9
Number of major customers | Major_Customer	32

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Segment Financial Information - Condensed Financial Information of Segments after Elimination of Unrealized Intersegment Gain (Loss) (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2014 MXN ($)
Sales:
Trade		$ 1,385,899,150	$ 1,065,118,590	$ 1,153,450,357
Services income	$ 562,528	11,130,569	8,974,642	8,310,035
(Reversal) impairment of wells pipelines, properties, plant and equipment, net		151,444,560	(331,314,343)	477,944,690
Benefit from change in pension plan				(92,177,089)
Cost of sales	50,751,509	1,004,204,880	865,822,221	891,964,606
Gross income (loss)	12,199,118	241,380,279	539,585,354	(115,971,815)
Other revenues (expenses), net	261,493	5,174,076	22,649,606	(875,487)
Distribution, transportation and sales expenses	1,106,282	21,889,670	25,231,240	28,928,639
Administrative expenses	6,061,620	119,939,454	112,653,533	112,472,095
Benefit from change in pension plan				(103,860,955)
Operating income (loss)		104,725,231	424,350,187	(154,387,081)
Financing income	817,006	16,165,853	13,749,255	14,990,859
Financing cost	(5,945,638)	(117,644,548)	(98,844,464)	(67,773,593)
Derivative financial instruments (cost) income, net		25,338,324	(14,000,987)	(21,449,877)
Foreign exchange (loss) income, net	1,171,702	23,184,122	(254,012,743)	(154,765,574)
(Loss) profit sharing in joint ventures and associates	18,216	360,440	2,135,845	2,318,115
Taxes, duties and other		332,980,041	264,521,435	331,500,247
Net (loss) income	(14,193,909)	(280,850,619)	(191,144,342)	(712,567,398)
Total current assets	18,372,255		357,815,923	267,200,497	$ 363,526,290
Investments in joint ventures and associates	844,373		20,737,509	24,165,599	16,707,364
Wells, pipelines, properties, plant and equipment, net	72,599,743		1,667,742,248	1,344,483,631	1,436,509,326
Total assets	107,749,252		2,329,886,024	1,775,654,200	2,132,002,114
Total current liabilities	19,666,099		426,189,886	443,407,721	389,127,185
Long-term debt	95,046,956		1,807,004,542	1,300,873,167	1,880,665,604
Employee benefits	63,600,101		1,220,409,436	1,279,385,441	1,258,436,122
Total liabilities	183,676,636		3,562,894,171	3,107,330,098	3,634,354,499
Equity (deficit), net	$ (75,927,384)		(1,233,008,147)	(1,331,675,898)	(1,502,352,385)	$ (767,720,854)
Depreciation and amortization		156,704,513	150,439,491	167,951,250
Net periodic cost of employee benefits			109,738,416	62,549,142	108,073,075
Acquisition of wells, pipelines, properties, plant and equipment		93,979,817	155,735,343	264,857,811
Exploration and Production [member]
Sales:
Intersegment		762,637,362	616,380,615	690,642,133
(Reversal) impairment of wells pipelines, properties, plant and equipment, net		129,350,315	(271,709,433)	394,396,580
Benefit from change in pension plan				(46,368,308)
Cost of sales		391,089,410	359,064,884	427,158,621
Gross income (loss)		242,197,637	529,025,164	(84,544,760)
Other revenues (expenses), net		10,204,045	27,346,794	(7,957,202)
Administrative expenses		58,539,119	54,509,047	18,454,281
Benefit from change in pension plan				(17,853,725)
Operating income (loss)		193,862,563	501,862,911	(93,102,518)
Financing income		121,293,404	56,040,129	25,852,078
Financing cost		(136,378,338)	(109,946,363)	(90,822,360)
Derivative financial instruments (cost) income, net		(1,613,874)
Foreign exchange (loss) income, net		10,043,316	(217,166,718)	(132,165,427)
(Loss) profit sharing in joint ventures and associates		(75,195)	(21,164)	(473,082)
Taxes, duties and other		338,169,260	276,647,448	376,682,705
Net (loss) income		(151,037,384)	(45,878,653)	(667,394,014)
Total current assets			983,260,710	709,252,019	1,036,063,541
Investments in joint ventures and associates			139,523	919,654	64,328
Wells, pipelines, properties, plant and equipment, net			1,176,504,263	966,144,619	945,945,889
Total assets			2,206,418,541	1,698,909,240	2,058,036,405
Total current liabilities			340,011,451	278,507,394	284,656,058
Long-term debt			1,737,109,328	1,252,239,594	1,826,843,268
Employee benefits			362,312,386	379,150,943	372,032,958
Total liabilities			2,533,221,665	1,985,557,185	2,570,412,398
Equity (deficit), net			(326,803,124)	(286,647,945)	(512,375,993)
Depreciation and amortization		127,742,568	124,329,921	144,567,149
Net periodic cost of employee benefits			32,617,215	23,608,485	32,794,386
Acquisition of wells, pipelines, properties, plant and equipment		67,845,989	70,418,370	184,786,051
Industrial Transformation [member]
Sales:
Trade		857,456,146	648,088,013	740,190,020
Intersegment		150,360,283	117,096,378	126,294,195
Services income		6,116,937	5,565,604	7,549,061
(Reversal) impairment of wells pipelines, properties, plant and equipment, net		15,952,092	(52,498,881)	76,442,079
Benefit from change in pension plan				(45,808,781)
Cost of sales		1,004,683,554	823,763,927	876,531,944
Gross income (loss)		(6,702,280)	(515,051)	(33,131,966)
Other revenues (expenses), net		1,515,538	19,964,654	1,243,040
Distribution, transportation and sales expenses		26,049,566	50,792,317	35,292,527
Administrative expenses		38,994,887	34,183,846	40,529,587
Benefit from change in pension plan				(39,975,450)
Operating income (loss)		(70,231,195)	(65,526,560)	(67,735,590)
Financing income		11,427,907	11,056,345	2,789,535
Financing cost		(2,398,643)	(3,188,892)	(13,738,104)
Derivative financial instruments (cost) income, net		5,835	3,172	6,463
Foreign exchange (loss) income, net		4,924,209	(12,858,875)	(7,364,486)
(Loss) profit sharing in joint ventures and associates		485,224	649,520	671,868
Taxes, duties and other				1,839,021
Net (loss) income		(55,786,663)	(69,865,290)	(87,209,335)
Total current assets			795,237,287	313,801,630	570,380,888
Investments in joint ventures and associates			257,159	6,687,977	4
Wells, pipelines, properties, plant and equipment, net			311,432,174	246,463,069	286,423,735
Total assets			1,107,094,580	567,486,579	857,196,306
Total current liabilities			666,467,674	104,569,842	459,130,165
Long-term debt			31,495,027	16,707,005	25,437,147
Employee benefits			575,277,374	609,492,623	588,573,518
Total liabilities			1,278,138,290	735,280,560	1,077,108,748
Equity (deficit), net			(171,043,710)	(167,793,981)	(219,912,442)
Depreciation and amortization		17,935,112	17,425,472	20,916,796
Net periodic cost of employee benefits			52,886,397	21,392,600	52,538,989
Acquisition of wells, pipelines, properties, plant and equipment		14,678,182	32,254,531	68,935,841
Cogeneration and Services [member]
Sales:
Intersegment		114,233	51,913
Services income		334,755	132,521
Cost of sales		472,732	166,721	2,793
Gross income (loss)		(23,744)	17,713	(2,793)
Other revenues (expenses), net		2,646
Distribution, transportation and sales expenses		13,581	8,232	1,448
Administrative expenses		37,679	32,126	47,670
Operating income (loss)		(72,358)	(22,645)	(51,911)
Financing income		147
Financing cost		(19,882)	(12,055)	2,110
Foreign exchange (loss) income, net				(7,509)
Net (loss) income		(92,093)	(34,700)	(57,310)
Total current assets			388,422	655,239	179,807
Total assets			388,423	655,240	179,807
Total current liabilities			472,236	469,524	531,580
Employee benefits			191,876	61,171
Total liabilities			664,829	530,696	531,580
Equity (deficit), net			(276,406)	124,544	(351,773)
Net periodic cost of employee benefits			5,860	(298)
Drilling and Services [member]
Sales:
Intersegment		3,400,456	1,981,754	1,511,970
Services income		41,741	70,112
Cost of sales		468,171	143,956	706,896
Gross income (loss)		2,974,026	1,907,910	805,074
Other revenues (expenses), net		(31,454)	591,704	38
Distribution, transportation and sales expenses			6
Administrative expenses		888,776	983,560	8,553
Operating income (loss)		2,053,796	1,516,048	796,559
Financing income		57,313	72,995	43,690
Financing cost		(795,947)	(642,711)	(95,280)
Foreign exchange (loss) income, net		227,365	(1,570,317)	(92,046)
Taxes, duties and other		276,967	(481,581)	197,491
Net (loss) income		1,265,560	(142,404)	455,432
Total current assets			6,032,213	2,171,717	6,871,148
Wells, pipelines, properties, plant and equipment, net			21,023,629	22,647,454	18,956,882
Total assets			27,673,598	24,917,981	26,220,748
Total current liabilities			3,894,121	1,981,652	2,201,936
Long-term debt			12,489,423	12,031,849	11,258,734
Employee benefits			441,127	417,817	333,212
Total liabilities			16,853,202	14,431,318	13,886,424
Equity (deficit), net			10,820,396	10,486,663	12,334,324
Depreciation and amortization		2,368,123	2,559,357	612,741
Net periodic cost of employee benefits			31,491		39,697
Acquisition of wells, pipelines, properties, plant and equipment		418,283	2,053,139
Logistics [member]
Sales:
Intersegment		70,671,871	68,316,958	598,853
Services income		3,714,941	2,813,887	10,355,988
(Reversal) impairment of wells pipelines, properties, plant and equipment, net			(5,829,520)	5,829,519
Cost of sales		50,926,263	61,248,584	10,727,462
Gross income (loss)		23,460,549	15,711,781	(5,602,140)
Other revenues (expenses), net		(24,134,436)	(27,189,969)	26,941
Distribution, transportation and sales expenses		73,526	148,215	3,009
Administrative expenses		7,459,928	7,175,451	104,794
Operating income (loss)		(8,207,341)	(18,801,854)	(5,683,002)
Financing income		1,622,827	373,301	37
Financing cost		(2,307,427)	(481,741)	(61,153)
Foreign exchange (loss) income, net		613,099	(1,118,537)	(11,090)
(Loss) profit sharing in joint ventures and associates		(74)
Taxes, duties and other		(7,444,967)	(10,010,686)	(2,069,848)
Net (loss) income		(833,949)	(10,018,145)	(3,685,360)
Total current assets			22,087,801	49,162,929	49,391,784
Investments in joint ventures and associates					18,336
Wells, pipelines, properties, plant and equipment, net			86,695,514	58,078,603	119,647,553
Total assets			130,824,921	111,307,038	191,895,993
Total current liabilities			19,824,792	14,698,159	44,521,371
Long-term debt			4,382,109	4,850,905	2,814,640
Employee benefits			571,702	368,036	1,842,892
Total liabilities			29,336,417	19,917,100	56,706,251
Equity (deficit), net			101,488,504	91,389,938	135,189,742
Depreciation and amortization		4,562,140	2,230,557	337,364
Net periodic cost of employee benefits			30,340	(310)	(4,954)
Acquisition of wells, pipelines, properties, plant and equipment		5,189,409	26,344,495	1,544,224
Fertilizers [member]
Sales:
Trade		4,123,006	3,873,403	1,494,478
Intersegment		642,965	900,464	209,970
Services income		2,339	1,908	236
(Reversal) impairment of wells pipelines, properties, plant and equipment, net		1,935,500
Cost of sales		6,001,259	5,506,198	1,707,548
Gross income (loss)		(3,168,449)	(730,423)	(2,864)
Other revenues (expenses), net		9,013	32,710	14,680
Distribution, transportation and sales expenses		528,370	185,168	4,416
Administrative expenses		352,537	731,479	152,404
Operating income (loss)		(4,040,343)	(1,614,360)	(145,004)
Financing income		2,248	4,358	3,503
Financing cost		(211,004)	(20,217)
Foreign exchange (loss) income, net		(20,925)	(29,263)	(3,600)
Net (loss) income		(4,270,024)	(1,659,482)	(145,101)
Total current assets			1,724,967	1,594,643	3,155,476
Investments in joint ventures and associates				8,500
Wells, pipelines, properties, plant and equipment, net			7,771,634	7,405,969	5,713,998
Total assets			9,556,469	9,034,376	8,923,456
Total current liabilities			2,995,088	1,486,468	6,455,246
Employee benefits			20,362	12,533	98,361
Total liabilities			3,015,450	1,499,001	6,556,050
Equity (deficit), net			6,541,019	7,535,375	2,367,406
Depreciation and amortization		422,930	481,241	158,505
Net periodic cost of employee benefits			(1,178)		(1,999)
Acquisition of wells, pipelines, properties, plant and equipment		219,152	889,420	320,762
Ethylene [member]
Sales:
Trade		12,621,648	15,392,552	4,551,413
Intersegment		1,565,757	1,764,438	473,990
Services income		26,733	60,141	17,893
(Reversal) impairment of wells pipelines, properties, plant and equipment, net			(1,276,509)	1,276,512
Cost of sales		14,272,340	13,936,213	4,965,414
Gross income (loss)		(58,202)	4,557,427	(1,198,630)
Other revenues (expenses), net		23,030	63,989	19,909
Distribution, transportation and sales expenses		334,663	481,727	62,071
Administrative expenses		1,105,554	2,101,834	519,351
Operating income (loss)		(1,475,389)	2,037,855	(1,760,143)
Financing income		46,113	64,582	7,728
Financing cost		(1,964)	(2,980)
Foreign exchange (loss) income, net		(10,486)	(2,843)	(2,802)
Net (loss) income		(1,441,726)	2,096,614	(1,755,217)
Total current assets			5,817,262	4,988,511	3,994,381
Wells, pipelines, properties, plant and equipment, net			20,086,650	18,480,684	19,008,822
Total assets			26,007,319	23,705,118	23,142,045
Total current liabilities			3,879,828	4,534,980	2,183,654
Employee benefits			21,893	3,611	105,033
Total liabilities			3,901,722	4,538,591	2,308,890
Equity (deficit), net			22,105,597	19,166,527	20,833,155
Depreciation and amortization		1,688,493	1,395,232	442,504
Net periodic cost of employee benefits			1,424		(12,561)
Acquisition of wells, pipelines, properties, plant and equipment		475,196	1,724,690	1,882,108
Trading Companies [member]
Sales:
Trade		508,539,112	395,118,117	407,214,446
Intersegment		539,193,190	405,293,283	353,137,149
Services income		66,621	236,230	661,683
Cost of sales		1,031,997,901	783,691,245	749,655,199
Gross income (loss)		15,801,022	16,956,385	11,358,079
Other revenues (expenses), net		307,212	3,412,711	1,666,783
Distribution, transportation and sales expenses		375,482	229,432	428,613
Administrative expenses		1,564,859	1,157,182	1,967,581
Operating income (loss)		14,167,893	18,982,482	10,628,668
Financing income		905,405	1,098,079	1,147,870
Financing cost		(1,328,827)	(1,342,351)	(1,299,580)
Derivative financial instruments (cost) income, net		(772,143)	(1,951,959)	1,347,323
Foreign exchange (loss) income, net		(4,318)	174,866	(49,190)
(Loss) profit sharing in joint ventures and associates		1,049,809	1,586,503	2,056,259
Taxes, duties and other		1,972,718	7,380,870	5,134,176
Net (loss) income		12,045,101	11,166,750	8,697,174
Total current assets			125,081,531	73,116,155	158,414,445
Investments in joint ventures and associates			17,568,893	11,845,489	15,805,506
Wells, pipelines, properties, plant and equipment, net			6,691,813	3,045,704	6,739,231
Total assets			155,376,864	93,266,620	186,808,899
Total current liabilities			78,894,485	34,749,438	112,046,527
Long-term debt			3,597,938	3,607,840	2,712,654
Employee benefits			(749,034)	(59,581)	(966,238)
Total liabilities			86,885,889	41,420,792	116,842,881
Equity (deficit), net			68,490,975	51,845,828	69,966,018
Depreciation and amortization		(19,798)	86,707	84,493
Net periodic cost of employee benefits			(552,735)	(119,819)	16,166
Acquisition of wells, pipelines, properties, plant and equipment		321,145	1,019,484	677,314
Corporate and Other Operating Subsidiary Companies [member]
Sales:
Trade		3,159,238	2,646,505
Intersegment		79,031,944	50,683,175	18,296,515
Services income		826,502	473,415	505,032
(Reversal) impairment of wells pipelines, properties, plant and equipment, net		4,206,653
Cost of sales		33,033,923	7,260,043	2,791,350
Gross income (loss)		45,777,108	46,543,052	16,010,197
Other revenues (expenses), net		(5,344,872)	(906,183)	2,219,539
Distribution, transportation and sales expenses		59,043	49,162	254
Administrative expenses		62,001,641	60,497,232	61,609,813
Benefit from change in pension plan				(46,031,780)
Operating income (loss)		(21,628,448)	(14,909,525)	2,651,449
Financing income		145,907,795	125,964,466	110,816,691
Financing cost		(239,003,771)	(163,400,779)	(87,289,616)
Derivative financial instruments (cost) income, net		27,718,506	(12,052,200)	(22,803,663)
Foreign exchange (loss) income, net		7,411,862	(21,441,056)	(15,069,424)
(Loss) profit sharing in joint ventures and associates		(212,666,494)	(117,426,818)	(749,900,890)
Taxes, duties and other		6,063	(9,014,616)	(50,283,298)
Net (loss) income		(292,266,613)	(194,251,296)	(711,312,155)
Total current assets			613,881,578	275,582,816	506,187,594
Investments in joint ventures and associates			(247,349,711)	(242,233,405)	(465,026,224)
Wells, pipelines, properties, plant and equipment, net			37,536,571	22,217,529	34,073,216
Total assets			2,359,024,145	1,443,189,885	2,111,740,735
Total current liabilities			1,497,612,971	1,157,183,570	1,439,097,882
Long-term debt			1,757,315,685	1,285,676,066	1,837,690,559
Employee benefits			282,321,750	289,938,288	296,416,386
Total liabilities			3,553,477,189	2,747,910,113	3,587,988,972
Equity (deficit), net			(1,194,453,044)	(1,304,720,228)	(1,476,248,237)
Depreciation and amortization		2,004,945	1,931,004	831,698
Net periodic cost of employee benefits			24,719,602	17,668,484	22,703,351
Acquisition of wells, pipelines, properties, plant and equipment		4,832,461	21,031,214	6,711,511
Intersegment Eliminations [member]
Sales:
Intersegment		(1,607,618,061)	(1,262,468,978)	(1,191,164,775)
Services income			(379,176)	(10,779,858)
Cost of sales		(1,528,740,673)	(1,188,959,550)	(1,182,282,621)
Gross income (loss)		(78,877,388)	(73,888,604)	(19,662,012)
Other revenues (expenses), net		22,623,354	(666,804)	1,890,785
Distribution, transportation and sales expenses		(5,544,561)	(26,663,019)	(6,863,699)
Administrative expenses		(51,005,526)	(48,718,224)	(10,921,939)
Operating income (loss)		296,053	825,835	14,411
Financing income		(265,097,306)	(180,925,000)	(125,670,273)
Financing cost		264,801,255	180,193,625	125,530,390
(Loss) profit sharing in joint ventures and associates		211,567,170	117,347,804	749,963,960
Net (loss) income		$ 211,567,172	117,442,264	749,838,488
Total current assets			(2,195,695,848)	(1,163,125,162)	(1,971,112,774)
Investments in joint ventures and associates			250,121,645	246,937,384	465,845,414
Total assets			(3,692,478,836)	(2,196,817,877)	(3,332,142,280)
Total current liabilities			(2,187,862,760)	(1,154,773,306)	(1,961,697,234)
Long-term debt			(1,739,384,968)	(1,274,240,092)	(1,826,091,398)
Total liabilities			(3,942,600,482)	(2,443,755,258)	(3,797,987,695)
Equity (deficit), net			$ 250,121,646	$ 246,937,381	$ 465,845,415

XML

Segment Financial Information - Schedule of Accounting Reconciliations Between Individual and Consolidated Information (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)	Dec. 31, 2017 MXN ($)
Disclosure of operating segments [line items]
Total consolidated sales	$ 70,604,483	$ 1,397,029,719	$ 1,074,093,232	$ 1,161,760,392
Total consolidated operating (loss) income		104,725,231	424,350,187	(154,387,081)
Total consolidated net (loss) income	(14,193,909)	(280,850,619)	(191,144,342)	(712,567,398)
Total consolidated assets	107,749,252		2,329,886,024	1,775,654,200	$ 2,132,002,114
Total consolidated liabilities	$ 183,676,636		3,562,894,171	3,107,330,098	3,634,354,499
Exploration and Production [member]
Disclosure of operating segments [line items]
Total consolidated sales		762,637,362	616,380,615	690,642,133
Total consolidated operating (loss) income		193,862,563	501,862,911	(93,102,518)
Total consolidated net (loss) income		(151,037,384)	(45,878,653)	(667,394,014)
Total consolidated assets			2,206,418,541	1,698,909,240	2,058,036,405
Total consolidated liabilities			2,533,221,665	1,985,557,185	2,570,412,398
Exploration and Production [member] | By segment [member]
Disclosure of operating segments [line items]
Total consolidated sales		762,637,362	616,380,615	690,642,133
Total consolidated operating (loss) income		194,814,292	503,679,153	(89,473,302)
Total consolidated net (loss) income		(150,388,699)	(44,069,001)	(663,719,119)
Total consolidated assets			2,232,052,453		2,084,553,745
Total consolidated liabilities			2,533,221,665		2,570,412,398
Exploration and Production [member] | unrealized Intersegment Sales [member]
Disclosure of operating segments [line items]
Total consolidated assets			483,230		858,094
Exploration and Production [member] | unrealized Gain due to Production Cost Valuation of Inventory [member]
Disclosure of operating segments [line items]
Total consolidated operating (loss) income		(496,329)	(273,237)	(251,995)
Total consolidated net (loss) income		(496,329)	(273,237)	(251,995)
Total consolidated assets			(3,246,782)		(3,657,242)
Exploration and Production [member] | Capitalized Refined Products [member]
Disclosure of operating segments [line items]
Total consolidated operating (loss) income		(574,381)	(1,661,986)	(3,496,201)
Total consolidated net (loss) income		(574,381)	(1,661,986)	(3,496,201)
Total consolidated assets			(1,661,986)		(574,381)
Exploration and Production [member] | Amortization of Capitalized Interest [member]
Disclosure of operating segments [line items]
Total consolidated operating (loss) income		118,981	118,981	118,980
Total consolidated net (loss) income		118,981	118,981	118,980
Total consolidated assets			118,981		118,981
Exploration and Production [member] | Depreciation and impairment of revaluated transferred assets net of deferred taxess [member]
Disclosure of operating segments [line items]
Total consolidated assets			(20,585,300)
Exploration and Production [member] | Equity Method Elimination [member]
Disclosure of operating segments [line items]
Total consolidated net (loss) income		303,044	6,590	(45,679)
Total consolidated assets			(742,055)		(759,624)
Exploration and Production [member] | Depreciation of Revaluated Assets [member]
Disclosure of operating segments [line items]
Total consolidated assets					(22,503,168)
Industrial Transformation [member]
Disclosure of operating segments [line items]
Total consolidated sales		1,013,933,366	770,749,995	874,033,276
Total consolidated operating (loss) income		(70,231,195)	(65,526,560)	(67,735,590)
Total consolidated net (loss) income		(55,786,663)	(69,865,290)	(87,209,335)
Total consolidated assets			1,107,094,580	567,486,579	857,196,306
Total consolidated liabilities			1,278,138,290	735,280,560	1,077,108,748
Industrial Transformation [member] | By segment [member]
Disclosure of operating segments [line items]
Total consolidated sales		1,015,157,118	771,597,427	874,630,488
Total consolidated operating (loss) income		(59,989,652)	(60,347,367)	(88,819,558)
Total consolidated net (loss) income		(44,599,751)	(61,639,067)	(107,164,261)
Total consolidated assets			1,151,907,566		912,770,881
Total consolidated liabilities			1,282,558,220		1,081,528,677
Industrial Transformation [member] | unrealized Intersegment Sales [member]
Disclosure of operating segments [line items]
Total consolidated sales		(1,223,752)	(847,432)	(597,212)
Total consolidated operating (loss) income		(1,223,752)	(847,432)	(597,212)
Total consolidated net (loss) income		(1,223,752)	(847,432)	(597,212)
Total consolidated assets			(4,158,101)		(5,389,977)
Total consolidated liabilities			(4,419,930)		(4,419,929)
Industrial Transformation [member] | unrealized Gain due to Production Cost Valuation of Inventory [member]
Disclosure of operating segments [line items]
Total consolidated operating (loss) income		(9,017,791)	3,572,498	21,681,180
Total consolidated net (loss) income		(9,017,791)	3,572,498	21,681,180
Total consolidated assets			(33,361,438)		(42,379,229)
Industrial Transformation [member] | Capitalized Refined Products [member]
Disclosure of operating segments [line items]
Total consolidated operating (loss) income			(7,904,259)
Total consolidated net (loss) income			(7,904,259)
Industrial Transformation [member] | Amortization of Capitalized Interest [member]
Disclosure of operating segments [line items]
Total consolidated assets					8,123
Industrial Transformation [member] | Equity Method Elimination [member]
Disclosure of operating segments [line items]
Total consolidated net (loss) income		(945,369)	(3,047,030)	(1,129,042)
Total consolidated assets			(7,293,447)		(7,813,492)
Cogeneration and Services [member]
Disclosure of operating segments [line items]
Total consolidated sales		448,988	184,434
Total consolidated operating (loss) income		(72,358)	(22,645)	(51,911)
Total consolidated net (loss) income		(92,093)	(34,700)	(57,310)
Total consolidated assets			388,423	655,240	179,807
Total consolidated liabilities			664,829	530,696	531,580
Cogeneration and Services [member] | By segment [member]
Disclosure of operating segments [line items]
Total consolidated sales		448,988	184,434
Total consolidated operating (loss) income		(72,358)	(22,645)	(51,911)
Total consolidated net (loss) income		(358,862)	(381,214)	(57,310)
Total consolidated assets			425,141		179,807
Total consolidated liabilities			664,829		531,580
Cogeneration and Services [member] | Equity Method Elimination [member]
Disclosure of operating segments [line items]
Total consolidated net (loss) income		266,769	346,514
Total consolidated assets			(36,718)
Drilling and Services [member]
Disclosure of operating segments [line items]
Total consolidated sales		3,442,197	2,051,866	1,511,970
Total consolidated operating (loss) income		2,053,796	1,516,048	796,559
Total consolidated net (loss) income		1,265,560	(142,404)	455,432
Total consolidated assets			27,673,598	24,917,981	26,220,748
Total consolidated liabilities			16,853,202	14,431,318	13,886,424
Drilling and Services [member] | By segment [member]
Disclosure of operating segments [line items]
Total consolidated sales		6,679,132	6,263,093	1,511,970
Total consolidated operating (loss) income		882,692	1,271,202	700,748
Total consolidated net (loss) income		345,913	(387,250)	359,621
Total consolidated assets			30,990,147		28,256,876
Total consolidated liabilities			16,457,347		13,186,297
Drilling and Services [member] | unrealized Intersegment Sales [member]
Disclosure of operating segments [line items]
Total consolidated sales		(3,236,935)	(4,211,227)
Total consolidated operating (loss) income		(3,236,935)	(4,211,227)
Total consolidated net (loss) income		(3,236,935)	(4,211,227)
Total consolidated liabilities			395,855		700,127
Drilling and Services [member] | unrealized Gain due to Production Cost Valuation of Inventory [member]
Disclosure of operating segments [line items]
Total consolidated operating (loss) income		2,932,663	3,815,371
Total consolidated net (loss) income		2,932,663	3,815,371
Drilling and Services [member] | Depreciation and impairment of revaluated transferred assets net of deferred taxess [member]
Disclosure of operating segments [line items]
Total consolidated operating (loss) income		1,475,376	640,702	95,811
Total consolidated net (loss) income			640,702	95,811
Total consolidated assets			(3,316,549)
Drilling and Services [member] | Depreciation of Revaluated Assets [member]
Disclosure of operating segments [line items]
Total consolidated net (loss) income		1,223,919
Total consolidated assets					(2,036,128)
Logistics [member]
Disclosure of operating segments [line items]
Total consolidated sales		74,386,812	71,130,845	10,954,841
Total consolidated operating (loss) income		(8,207,341)	(18,801,854)	(5,683,002)
Total consolidated net (loss) income		(833,949)	(10,018,145)	(3,685,360)
Total consolidated assets			130,824,921	111,307,038	191,895,993
Total consolidated liabilities			29,336,417	19,917,100	56,706,251
Logistics [member] | By segment [member]
Disclosure of operating segments [line items]
Total consolidated sales		74,386,812	71,130,845	10,954,841
Total consolidated operating (loss) income		(61,696,313)	(25,701,065)	(6,875,252)
Total consolidated net (loss) income		(40,300,942)	(16,917,356)	(4,877,610)
Total consolidated assets			254,615,026		276,537,764
Total consolidated liabilities			29,336,417		56,706,251
Logistics [member] | unrealized Intersegment Sales [member]
Disclosure of operating segments [line items]
Total consolidated assets					7,183
Logistics [member] | Depreciation and impairment of revaluated transferred assets net of deferred taxess [member]
Disclosure of operating segments [line items]
Total consolidated operating (loss) income		53,488,972	6,899,211	1,192,250
Total consolidated net (loss) income			6,899,211	1,192,250
Total consolidated assets			(123,790,105)
Logistics [member] | Equity Method Elimination [member]
Disclosure of operating segments [line items]
Total consolidated net (loss) income		333
Total consolidated assets					(91,123)
Logistics [member] | Depreciation of Revaluated Assets [member]
Disclosure of operating segments [line items]
Total consolidated net (loss) income		39,466,660
Total consolidated assets					(84,557,831)
Fertilizers [member]
Disclosure of operating segments [line items]
Total consolidated sales		4,768,310	4,775,775	1,704,684
Total consolidated operating (loss) income		(4,040,343)	(1,614,360)	(145,004)
Total consolidated net (loss) income		(4,270,024)	(1,659,482)	(145,101)
Total consolidated assets			9,556,469	9,034,376	8,923,456
Total consolidated liabilities			3,015,450	1,499,001	6,556,050
Fertilizers [member] | By segment [member]
Disclosure of operating segments [line items]
Total consolidated sales		4,795,196	4,775,775	1,704,684
Total consolidated operating (loss) income		(7,148,431)	(2,877,725)	(262,145)
Total consolidated net (loss) income		(8,616,130)	(7,820,835)	(262,242)
Total consolidated assets			10,421,225		17,689,305
Total consolidated liabilities			3,015,450		6,556,050
Fertilizers [member] | unrealized Intersegment Sales [member]
Disclosure of operating segments [line items]
Total consolidated sales		(26,886)
Total consolidated operating (loss) income		(26,886)
Total consolidated net (loss) income		(26,886)
Fertilizers [member] | unrealized Gain due to Production Cost Valuation of Inventory [member]
Disclosure of operating segments [line items]
Total consolidated operating (loss) income			905,910
Total consolidated net (loss) income			905,910
Total consolidated assets					(26,886)
Fertilizers [member] | Depreciation and impairment of revaluated transferred assets net of deferred taxess [member]
Disclosure of operating segments [line items]
Total consolidated operating (loss) income		3,134,974	357,455	117,141
Total consolidated net (loss) income			357,455	117,141
Total consolidated assets			(5,300,044)
Fertilizers [member] | Equity Method Elimination [member]
Disclosure of operating segments [line items]
Total consolidated net (loss) income		1,238,018	4,897,988
Total consolidated assets			4,435,288		(6,573,895)
Fertilizers [member] | Depreciation of Revaluated Assets [member]
Disclosure of operating segments [line items]
Total consolidated net (loss) income		3,134,974
Total consolidated assets					(2,165,068)
Ethylene [member]
Disclosure of operating segments [line items]
Total consolidated sales		14,214,138	17,217,131	5,043,296
Total consolidated operating (loss) income		(1,475,389)	2,037,855	(1,760,143)
Total consolidated net (loss) income		(1,441,726)	2,096,614	(1,755,217)
Total consolidated assets			26,007,319	23,705,118	23,142,045
Total consolidated liabilities			3,901,722	4,538,591	2,308,890
Ethylene [member] | By segment [member]
Disclosure of operating segments [line items]
Total consolidated sales		14,214,138	17,217,131	5,048,600
Total consolidated operating (loss) income		(4,698,838)	(3,504,812)	(2,288,747)
Total consolidated net (loss) income		(5,866,542)	(3,780,706)	(2,314,774)
Total consolidated assets			43,067,636		35,498,783
Total consolidated liabilities			3,901,722		2,308,890
Ethylene [member] | unrealized Intersegment Sales [member]
Disclosure of operating segments [line items]
Total consolidated sales				(5,304)
Total consolidated operating (loss) income				(5,304)
Total consolidated net (loss) income				(5,304)
Total consolidated assets			(5,304)		(5,303)
Ethylene [member] | unrealized Gain due to Production Cost Valuation of Inventory [member]
Disclosure of operating segments [line items]
Total consolidated operating (loss) income			(2,163)	2,163
Total consolidated net (loss) income			(2,163)	2,163
Ethylene [member] | Depreciation and impairment of revaluated transferred assets net of deferred taxess [member]
Disclosure of operating segments [line items]
Total consolidated operating (loss) income		3,223,449	5,544,830	531,745
Total consolidated net (loss) income			5,544,830	531,745
Total consolidated assets			(12,746,136)
Ethylene [member] | Equity Method Elimination [member]
Disclosure of operating segments [line items]
Total consolidated net (loss) income		1,201,367	334,653	30,953
Total consolidated assets			(4,308,877)		(2,828,749)
Ethylene [member] | Depreciation of Revaluated Assets [member]
Disclosure of operating segments [line items]
Total consolidated net (loss) income		3,223,449
Total consolidated assets					(9,522,686)
Trading Companies [member]
Disclosure of operating segments [line items]
Total consolidated sales		1,047,798,923	800,647,630	761,013,278
Total consolidated operating (loss) income		14,167,893	18,982,482	10,628,668
Total consolidated net (loss) income		12,045,101	11,166,750	8,697,174
Total consolidated assets			155,376,864	93,266,620	186,808,899
Total consolidated liabilities			86,885,889	41,420,792	116,842,881
Trading Companies [member] | By segment [member]
Disclosure of operating segments [line items]
Total consolidated sales		1,047,874,453	800,979,076	761,213,475
Total consolidated operating (loss) income		14,490,017	19,526,997	10,334,138
Total consolidated net (loss) income		5,200,268	11,711,265	8,402,644
Total consolidated assets			170,782,928		195,538,239
Total consolidated liabilities			85,392,123		116,648,398
Trading Companies [member] | unrealized Intersegment Sales [member]
Disclosure of operating segments [line items]
Total consolidated sales		(75,530)	(331,446)	(200,197)
Total consolidated operating (loss) income		(75,530)	(331,446)	(200,197)
Total consolidated net (loss) income		(75,530)	(331,446)	(200,197)
Total consolidated assets			(332,529)		(408,059)
Total consolidated liabilities			1,493,766		194,483
Trading Companies [member] | unrealized Gain due to Production Cost Valuation of Inventory [member]
Disclosure of operating segments [line items]
Total consolidated operating (loss) income		(246,594)	(213,069)	494,727
Total consolidated net (loss) income		(246,594)	(213,069)	494,727
Total consolidated assets			(5,688,341)		(7,163,664)
Trading Companies [member] | Amortization of Capitalized Interest [member]
Disclosure of operating segments [line items]
Total consolidated assets			(424,198)
Trading Companies [member] | Depreciation and impairment of revaluated transferred assets net of deferred taxess [member]
Disclosure of operating segments [line items]
Total consolidated assets			(652)
Trading Companies [member] | Equity Method Elimination [member]
Disclosure of operating segments [line items]
Total consolidated net (loss) income		7,166,957
Total consolidated assets			(8,960,344)		(732,768)
Trading Companies [member] | Depreciation of Revaluated Assets [member]
Disclosure of operating segments [line items]
Total consolidated assets					(424,849)
Corporate and Other Operating Subsidiary Companies [member]
Disclosure of operating segments [line items]
Total consolidated sales		83,017,684	53,803,095	18,801,547
Total consolidated operating (loss) income		(21,628,448)	(14,909,525)	2,651,449
Total consolidated net (loss) income		(292,266,613)	(194,251,296)	(711,312,155)
Total consolidated assets			2,359,024,145	1,443,189,885	2,111,740,735
Total consolidated liabilities			3,553,477,189	2,747,910,113	3,587,988,972
Corporate and Other Operating Subsidiary Companies [member] | By segment [member]
Disclosure of operating segments [line items]
Total consolidated sales		83,017,684	53,803,095	18,801,547
Total consolidated operating (loss) income		(21,628,448)	(14,909,525)	2,651,449
Total consolidated net (loss) income		$ (292,266,613)	(194,251,296)	$ (711,312,155)
Total consolidated assets			2,359,024,145		2,111,740,735
Total consolidated liabilities			$ 3,553,477,189		$ 3,587,988,972

XML

Segment Financial Information - Supplemental Geographic Information (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure of operating segments [line items]
Domestic sales	$ 44,340,898	$ 877,360,038	$ 670,000,473	$ 746,235,912
Total export sales	25,701,057	508,539,112	395,118,117	407,214,445
Services income	562,528	11,130,569	8,974,642	8,310,035
Total sales	$ 70,604,483	1,397,029,719	1,074,093,232	1,161,760,392
UNITED STATES
Disclosure of operating segments [line items]
Total export sales		302,912,999	221,954,461	266,826,499
Canada, Central and South America [member]
Disclosure of operating segments [line items]
Total export sales		13,943,080	14,058,897	11,027,813
Europe [member]
Disclosure of operating segments [line items]
Total export sales		71,470,613	64,348,997	58,707,787
Other [member]
Disclosure of operating segments [line items]
Total export sales		$ 120,212,420	$ 94,755,762	$ 70,652,346

XML

Segment Financial Information - Schedule of Income by Product (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure of operating segments [line items]
Total domestic sales	$ 44,340,898	$ 877,360,038	$ 670,000,473	$ 746,235,912
Total export sales	$ 25,701,057	508,539,112	395,118,117	407,214,445
Refined Petroleum Products and Derivatives [member]
Disclosure of operating segments [line items]
Total domestic sales		784,048,048	578,718,674	660,573,780
Total export sales		109,615,457	92,705,248	118,129,615
Gas [member]
Disclosure of operating segments [line items]
Total domestic sales		70,930,855	59,648,576	54,497,824
Total export sales		21,675	20,995	27,283
Petrochemical Products [member]
Disclosure of operating segments [line items]
Total domestic sales		22,381,135	31,633,223	31,164,308
Total export sales		18,440,833	13,766,080	887,096
Crude oil [member]
Disclosure of operating segments [line items]
Total export sales		$ 380,461,147	$ 288,625,794	$ 288,170,451

XML

Cash, Cash Equivalents and Restricted Cash - Summary of Cash and Cash Equivalents (Detail) $ in Thousands, $ in Thousands	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)	Dec. 31, 2014 MXN ($)
Cash and cash equivalents [abstract]
Cash on hand and in banks		$ 55,871,127		$ 71,430,427
Highly liquid investments		41,980,627		92,102,086
Cash and cash equivalents	$ 4,945,330	$ 97,851,754	$ 8,264,769	$ 163,532,513	$ 109,368,880	$ 117,988,528

XML

Cash, Cash Equivalents and Restricted Cash - Summary of Restricted Cash (Detail) $ in Thousands	Dec. 31, 2016 MXN ($)
Disclosure Of Restricted Cash And Cash Equivalents [Abstract]
Restricted cash	$ 10,478,626

XML

Cash, Cash Equivalents and Restricted Cash - Additional Information (Detail) - USD ($) $ in Thousands	Apr. 06, 2017	Dec. 31, 2016
Collateral [member]
Disclosure of Restricted Cash and Cash Equivalents [Line Items]
Deposit amount		$ 41,319
Pemex exploration and production [member]
Disclosure of Restricted Cash and Cash Equivalents [Line Items]
Deposit amount		$ 465,060
Settlement amount paid	$ 435,000

XML

Accounts Receivable, Net - Summary of Accounts Receivable and Other Receivables (Detail) $ in Thousands, $ in Thousands	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)
Trade and Other Receivables [Line Items]
Accounts receivable, net	$ 8,624,239	$ 170,645,234	$ 133,220,527
Domestic customers [member]
Trade and Other Receivables [Line Items]
Accounts receivable, net		60,057,141	41,884,579
Export customers [member]
Trade and Other Receivables [Line Items]
Accounts receivable, net		54,428,883	34,859,341
Sundry debtors [member]
Trade and Other Receivables [Line Items]
Accounts receivable, net		26,105,703	18,736,922
Taxes recovered and prepaid taxes [member]
Trade and Other Receivables [Line Items]
Accounts receivable, net		23,039,023	29,361,303
Employees and officers [member]
Trade and Other Receivables [Line Items]
Accounts receivable, net		5,681,478	6,054,251
Advances to suppliers [member]
Trade and Other Receivables [Line Items]
Accounts receivable, net		1,250,846	2,246,437
Other Current Receivables [member]
Trade and Other Receivables [Line Items]
Accounts receivable, net		$ 82,160	$ 77,694

XML

Accounts Receivable, Net - Schedule of Breakdown of Accounts Receivable Based on Credit History (Detail) - MXN ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Domestic customers [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	$ 60,057,141	$ 41,884,579
Domestic customers [member] | 1 to 30 days [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	10,188,070	1,767,718
Domestic customers [member] | 31 to 60 days [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	4,081,862	658,456
Domestic customers [member] | 61 to 90 days [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	777,409	263,447
Domestic customers [member] | More than 90 days [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	11,345,933	1,016,553
Domestic customers [member] | Past due [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	26,393,274	3,706,174
Domestic customers [member] | Impaired (reserved) [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	(951,932)	(458,428)
Domestic customers [member] | Unimpaired [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	25,441,342	3,247,746
Domestic customers [member] | Current [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	34,615,799	38,636,833
Export customers [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	54,428,883	34,859,341
Export customers [member] | 1 to 30 days [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	334,155	341,184
Export customers [member] | 31 to 60 days [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable		6,824
Export customers [member] | 61 to 90 days [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable		35,372
Export customers [member] | More than 90 days [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	315,888	624,157
Export customers [member] | Past due [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	650,043	1,007,537
Export customers [member] | Impaired (reserved) [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	(272,813)	(374,699)
Export customers [member] | Unimpaired [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	377,230	632,838
Export customers [member] | Current [member]
Trade and Other Receivables [Line Items]
Breakdown of accounts receivable	$ 54,051,653	$ 34,226,503

XML

Accounts Receivable, Net - Summary of Reconciliation for Impaired Accounts Receivable (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Domestic customers [member]
Trade and Other Receivables [Line Items]
Balance at the beginning of the year	$ (458,428)	$ (667,883)
Additions against income	(493,514)	(218,836)
Amount used	10	428,291
Balance at the end of the year	(951,932)	(458,428)
Export customers [member]
Trade and Other Receivables [Line Items]
Balance at the beginning of the year	(374,699)	(312,004)
Additions against income	(204,713)	(25,931)
Amount used	297,047
Translation effects	9,552	(36,764)
Balance at the end of the year	$ (272,813)	$ (374,699)

XML

Inventories, Net - Summary of Inventories (Detail) $ in Thousands, $ in Thousands	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)
Disclosure of Inventories [Line Items]
Inventories	$ 3,227,366	$ 63,858,930	$ 45,892,060
Refined and petrochemicals products [member]
Disclosure of Inventories [Line Items]
Inventories		27,862,384	21,534,846
Products in transit [member]
Disclosure of Inventories [Line Items]
Inventories		19,112,606	7,735,163
Crude oil [member]
Disclosure of Inventories [Line Items]
Inventories		11,445,780	11,391,310
Materials and products in stock [member]
Disclosure of Inventories [Line Items]
Inventories		5,172,779	4,721,834
Materials in transit [member]
Disclosure of Inventories [Line Items]
Inventories		180,711	419,547
Gas and condesate products [member]
Disclosure of Inventories [Line Items]
Inventories		$ 84,670	$ 89,360

XML

Held-for-sale Non-financial Assets - Additional Information (Detail) - MXN ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Disclosure Of Current Nonfinancial Asset Held For Sale [Line Items]
Non-financial assets held for sale reclassified to fixed assets	$ 4,652,314
Non-current assets held for sale [member]
Disclosure Of Current Nonfinancial Asset Held For Sale [Line Items]
Non-financial assets held for sale	$ 2,808,360	$ 7,460,674

XML

Available-For-Sale Non-Current Financial Assets - Additional Information (Detail) $ in Thousands, $ in Thousands								1 Months Ended		12 Months Ended
	Oct. 26, 2017 MXN ($) shares	Jun. 07, 2017 MXN ($) shares	Jan. 25, 2017 MXN ($) shares	Jan. 25, 2017 € / shares	Dec. 14, 2016 MXN ($) shares	Jun. 13, 2016 MXN ($) shares	Jan. 01, 2016 MXN ($) shares	Jan. 15, 2016 MXN ($) shares	Aug. 31, 2015 MXN ($) shares	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($) shares	Dec. 31, 2015 MXN ($)	Dec. 31, 2017 MXN ($)
Disclosure of available for sale financial assets [line items]
Value of non-current financial assets available-for-sale												$ 6,027,540
Loss on sale of financial asset										$ (178,087)	$ (3,523,748)
Other comprehensive income Loss on sale of financial asset										281,206	$ 5,564,130	207,817	$ (3,206,316)
Available-for-sale financial assets										$ 53,416		2,852,679		$ 1,056,918
Held-for-sale current non-financial assets												7,460,674		$ 1,056,918
Short-term Investments [Member]
Disclosure of available for sale financial assets [line items]
Available-for-sale financial assets												$ 2,417,123
Repsol S. A. [member]
Disclosure of available for sale financial assets [line items]
Number of shares held as non-current financial assets available-for-sale | shares							20,724,331	942,015
Value of non-current financial assets available-for-sale							$ 3,944,696	$ 188,490
Percentage of share capital held							1.48%
Repsol S. A. [member] | P.M.I. Holdings, B.V. [member]
Disclosure of available for sale financial assets [line items]
Number of shares held as non-current financial assets available-for-sale | shares		609,539			584,786	555,547			1,497,562			20,724,331
Value of non-current financial assets available-for-sale		$ 180,729			$ 165,346	$ 128,051			$ 435,556			$ 6,027,540
Valuation on the investment at fair value												207,817
Number of shares sold | shares	21,333,870		2,082,348
Average price per share | € / shares				€ 14.17
Value of shares sold	$ 7,342,807		$ 684,029
Loss on sale of financial asset	$ 3,523,748
Other comprehensive income Loss on sale of financial asset												$ 5,564,130

XML

Investments in Joint Ventures and Associates - Schedule of Investments in Joint Ventures and Associates (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure of Investments in Subsidiaries Joint Ventures and Associates [Line items]
Permanent investments in associates	$ 844,373	$ 16,707,364	$ 20,737,509	$ 24,165,599
Deer Park Refining Limited [member]
Disclosure of Investments in Subsidiaries Joint Ventures and Associates [Line items]
Permanent investments in associates		14,405,542	14,039,384
Percentage of investment	49.99%
Frontera Brownsville, LLC. [member]
Disclosure of Investments in Subsidiaries Joint Ventures and Associates [Line items]
Permanent investments in associates		471,085	478,414
Percentage of investment	50.00%
CH4 Energia, S. A. [member]
Disclosure of Investments in Subsidiaries Joint Ventures and Associates [Line items]
Permanent investments in associates		315,713	194,868
Percentage of investment	50.00%
Texas Frontera, LLC. [member]
Disclosure of Investments in Subsidiaries Joint Ventures and Associates [Line items]
Permanent investments in associates		239,782	260,828
Percentage of investment	50.00%
Petroquimica Mexicana de Vinilo. S. A. de C. V. [member]
Disclosure of Investments in Subsidiaries Joint Ventures and Associates [Line items]
Permanent investments in associates			4,309,050
Percentage of investment	44.09%
Sierrita Gas Pipeline LLC [member]
Disclosure of Investments in Subsidiaries Joint Ventures and Associates [Line items]
Permanent investments in associates		1,084,169	1,112,338
Percentage of investment	35.00%
Administracion Portuaria Integral de Dos Bocas, S.A. de C.V. [member]
Disclosure of Investments in Subsidiaries Joint Ventures and Associates [Line items]
Permanent investments in associates		64,328	139,523
Percentage of investment	40.00%
PMV Minera, S.A. de C.V. [member]
Disclosure of Investments in Subsidiaries Joint Ventures and Associates [Line items]
Permanent investments in associates		45,133	61,779
Percentage of investment	44.09%
Ductos el peninsular, S.A.P.I de C. V. [Member]
Disclosure of Investments in Subsidiaries Joint Ventures and Associates [Line items]
Permanent investments in associates		18,336	18,626
Percentage of investment	50.00%
Other-net [member]
Disclosure of Investments in Subsidiaries Joint Ventures and Associates [Line items]
Permanent investments in associates		$ 63,276	$ 122,699

XML

Investments in Joint Ventures and Associates - Schedule of Investments in Joint Ventures and Associates (Parenthetical) (Detail) $ in Thousands	Apr. 20, 2016 MXN ($)
Petroquimica Mexicana de Vinilo. S. A. de C. V. [member]
Disclosure of Investments in Subsidiaries Joint Ventures and Associates [Line items]
Damages value	$ 461,000

XML

Investments in Joint Ventures and Associates - Schedule Profit (loss) Sharing in Joint Ventures and Associates (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure of Investments in Associates and Other [Line Items]
Profit (loss) sharing in joint ventures and associates, net	$ 18,216	$ 360,440	$ 2,135,845	$ 2,318,115
Sierrita Gas Pipeline LLC [member]
Disclosure of Investments in Associates and Other [Line Items]
Profit (loss) sharing in joint ventures and associates, net		129,401	105,825	152,445
PMV Minera, S.A. de C.V. [member]
Disclosure of Investments in Associates and Other [Line Items]
Profit (loss) sharing in joint ventures and associates, net		6,253
Petroquimica Mexicana de Vinilo. S. A. de C. V. [member]
Disclosure of Investments in Associates and Other [Line Items]
Profit (loss) sharing in joint ventures and associates, net		(1,223,640)	(190,468)	(61,952)
Administracion Portuaria Integral de Dos Bocas, S.A. de C.V. [member]
Disclosure of Investments in Associates and Other [Line Items]
Profit (loss) sharing in joint ventures and associates, net		(75,195)
Other-net [member]
Disclosure of Investments in Associates and Other [Line Items]
Profit (loss) sharing in joint ventures and associates, net		117,988	144,512	143,782
Compania Mexicana de Exploraciones, S. A. de C. V. [member]
Disclosure of Investments in Associates and Other [Line Items]
Profit (loss) sharing in joint ventures and associates, net				(496,774)
Gasoductos de Chihuahua, S. de R. L. de C. V. [member]
Disclosure of Investments in Associates and Other [Line Items]
Profit (loss) sharing in joint ventures and associates, net			638,126	666,779
Deer Park Refining Limited [member]
Disclosure of Investments in Associates and Other [Line Items]
Profit (loss) sharing in joint ventures and associates, net		920,409	$ 1,437,850	$ 1,913,835
Ductos y Energticos del Norte, S.A. de C.V.[Member]
Disclosure of Investments in Associates and Other [Line Items]
Profit (loss) sharing in joint ventures and associates, net		360,092
CH4 Energia, S. A. [member]
Disclosure of Investments in Associates and Other [Line Items]
Profit (loss) sharing in joint ventures and associates, net		$ 125,132

XML

Investments in Joint Ventures and Associates - Schedule Profit (loss) Sharing in Joint Ventures and Associates (Parenthetical) (Detail) $ in Thousands, $ in Thousands		1 Months Ended
	Sep. 28, 2016 MXN ($)	Nov. 30, 2017 USD ($)
Gasoductos de Chihuahua, S. de R. L. de C. V. [member]
Disclosure of Investments in Associates and Other [Line Items]
Divestiture amount	$ 22,684,736
Ownership percentage	50.00%
Profit from divestiture	$ 15,211,039
Profit from divestiture	$ 15,211,039
Ductos y Energticos del Norte, S.A. de C.V.[Member]
Disclosure of Investments in Associates and Other [Line Items]
Divestiture amount		$ 3,141,710
Profit from divestiture		$ 3,139,103
Ownership percentage		50.00%
Profit from divestiture		$ 3,139,103

XML

Investments in Joint Ventures and Associates - Schedule of Condensed Financial Information of Major Investments Recognized Under the Equity Method (Detail) - MXN ($) $ in Thousands	1 Months Ended	12 Months Ended
	Aug. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Gasoductos de Chihuahua, S. de R. L. de C. V. [member]
Investment In Joint Ventures Accounted For Using Equity Method [Line Items]
Sales and other income	$ 3,798,666			$ 4,617,982
Costs and expenses	2,522,415			3,284,424
Net result	$ 1,276,251			1,333,558
Deer Park Refining Limited [member]
Investment In Joint Ventures Accounted For Using Equity Method [Line Items]
Sales and other income		$ 16,427,064	$ 16,750,155	16,658,705
Costs and expenses		14,586,061	13,874,172	12,830,653
Net result		1,841,003	2,875,983	$ 3,828,052
Sierrita Gas Pipeline LLC [member]
Investment In Joint Ventures Accounted For Using Equity Method [Line Items]
Financial position		3,518,036	3,244,811
Sales and other income		840,414	717,351
Costs and expenses		470,697	414,994
Net result		369,717	302,357
Sierrita Gas Pipeline LLC [member] | Total assets [member]
Investment In Joint Ventures Accounted For Using Equity Method [Line Items]
Financial position		3,518,036	3,244,811
Sierrita Gas Pipeline LLC [member] | Total liabilities [member]
Investment In Joint Ventures Accounted For Using Equity Method [Line Items]
Financial position		420,410	66,703
Sierrita Gas Pipeline LLC [member] | Total equity [member]
Investment In Joint Ventures Accounted For Using Equity Method [Line Items]
Financial position		3,097,626	3,178,108
Deer Park Refining Limited [member]
Investment In Joint Ventures Accounted For Using Equity Method [Line Items]
Financial position		41,075,547	42,428,275
Deer Park Refining Limited [member] | Total assets [member]
Investment In Joint Ventures Accounted For Using Equity Method [Line Items]
Financial position		41,075,547	42,428,275
Deer Park Refining Limited [member] | Total liabilities [member]
Investment In Joint Ventures Accounted For Using Equity Method [Line Items]
Financial position		12,261,581	14,346,643
Deer Park Refining Limited [member] | Total equity [member]
Investment In Joint Ventures Accounted For Using Equity Method [Line Items]
Financial position		$ 28,813,966	$ 28,081,632

XML

Investments in Joint Ventures, Associates and Other - Additional Information (Detail)			1 Months Ended		12 Months Ended
	Sep. 28, 2016	Feb. 06, 1997	Jul. 27, 2010	Mar. 31, 1993	Dec. 31, 2016 Barrels
Deer Park Refining Limited [member] | PMI NASA [member]
Disclosure of Investments in Associates and Other [Line Items]
Acquired percentage				50.00%
Texas Frontera, LLC. [member]
Disclosure of Investments in Associates and Other [Line Items]
Number of tanks					7
Barrels of capacity					120,000
Texas Frontera, LLC. [member] | PMI SUS [member]
Disclosure of Investments in Associates and Other [Line Items]
Acquired percentage			50.00%
Gasoductos de Chihuahua, S. de R. L. de C. V. [member]
Disclosure of Investments in Associates and Other [Line Items]
Acquired percentage	50.00%
Participation of share capital, percentage		50.00%

XML

Wells, Pipelines, Properties, Plant and Equipment, Net - Detailed Information About Property, Plant and Equipment (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		$ 1,667,742,248	$ 1,344,483,631
Acquisitions		93,979,817	155,735,343	$ 264,857,811
Impairment		151,444,560
Ending balance	$ 72,599,743	1,436,509,326	1,667,742,248	1,344,483,631
Gross carrying amount [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		3,268,797,613	2,807,149,644
Acquisitions		93,979,818	155,735,343
Reclassifications		(3,920,974)	(332,457)
Impairment		(151,444,560)	331,314,343
Disposals		(51,565,902)	(25,069,260)
Ending balance		3,155,845,995	3,268,797,613	2,807,149,644
Accumulated depreciation and amortization [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		(1,601,055,365)	(1,462,666,013)
Depreciation and amortization		(156,704,513)	(150,439,491)
Reclassifications		3,920,978	332,458
Disposals		34,502,231	11,717,681
Ending balance		(1,719,336,669)	(1,601,055,365)	(1,462,666,013)
Plants [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		398,429,131
Ending balance		362,001,214	398,429,131
Plants [member] | Gross carrying amount [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		758,446,110	648,412,014
Acquisitions		10,018,030	20,406,464
Reclassifications		3,146,955	150,817
Capitalization		43,033,864	15,943,630
Impairment		(48,020,616)	81,135,967
Disposals		(10,598,983)	(7,602,782)
Ending balance		756,025,360	758,446,110	648,412,014
Plants [member] | Accumulated depreciation and amortization [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		(360,016,979)	(321,283,906)
Depreciation and amortization		(45,709,123)	(44,549,443)
Reclassifications		2,799,244	(10,521)
Disposals		8,902,711	5,826,891
Ending balance		$ (394,024,147)	(360,016,979)	(321,283,906)
Plants [member] | Bottom of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Depreciation rates	3.00%	3.00%
Estimated useful lives	20 Years	20 Years
Plants [member] | Top of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Depreciation rates	5.00%	5.00%
Estimated useful lives	35 Years	35 Years
Drilling equipment [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		$ 20,326,541
Ending balance		$ 18,429,132	20,326,541
Depreciation rates	5.00%	5.00%
Estimated useful lives	20 Years	20 Years
Drilling equipment [member] | Gross carrying amount [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		$ 23,269,116	21,680,343
Acquisitions		418,283	1,629,710
Disposals		(244,283)	(40,937)
Ending balance		23,443,116	23,269,116	21,680,343
Drilling equipment [member] | Accumulated depreciation and amortization [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		(2,942,575)	(578,015)
Depreciation and amortization		(2,198,867)	(2,364,560)
Disposals		127,458
Ending balance		(5,013,984)	(2,942,575)	(578,015)
Pipelines [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		307,780,201
Ending balance		321,908,762	307,780,201
Pipelines [member] | Gross carrying amount [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		460,145,428	419,979,508
Acquisitions		7,054,793	1,265,011
Reclassifications		(53,349)	(1,268,887)
Capitalization		21,357,074	11,851,378
Impairment		2,226,771	31,967,407
Disposals		(8,862,541)	(3,648,989)
Ending balance		481,868,176	460,145,428	419,979,508
Pipelines [member] | Accumulated depreciation and amortization [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		(152,365,227)	(139,331,407)
Depreciation and amortization		(15,095,115)	(15,153,879)
Reclassifications		(72,841)	(166,632)
Disposals		7,573,769	2,286,691
Ending balance		$ (159,959,414)	(152,365,227)	(139,331,407)
Pipelines [member] | Bottom of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Depreciation rates	2.00%	2.00%
Estimated useful lives	15 Years	15 Years
Pipelines [member] | Top of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Depreciation rates	7.00%	7.00%
Estimated useful lives	45 Years	45 Years
Wells [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		$ 468,286,163
Ending balance		359,348,274	468,286,163
Wells [member] | Gross carrying amount [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		1,318,822,917	1,066,515,651
Acquisitions		14,937,882	8,239,480
Reclassifications			8,649,686
Capitalization		36,564,811	40,825,973
Impairment		(83,236,991)	198,974,994
Disposals		(19,340,709)	(4,382,867)
Ending balance		1,267,747,910	1,318,822,917	1,066,515,651
Wells [member] | Accumulated depreciation and amortization [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		(850,536,754)	(780,443,639)
Depreciation and amortization		(74,673,473)	(70,090,038)
Reclassifications			(3,077)
Disposals		16,810,591
Ending balance		(908,399,636)	(850,536,754)	(780,443,639)
Buildings [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		23,618,402
Ending balance		23,659,462	23,618,402
Buildings [member] | Gross carrying amount [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		62,743,033	66,284,466
Acquisitions		802,300	2,541,802
Reclassifications		98,245	(6,610,184)
Capitalization		1,265,246	1,085,323
Disposals		(208,353)	(558,374)
Ending balance		64,700,471	62,743,033	66,284,466
Buildings [member] | Accumulated depreciation and amortization [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		(39,124,631)	(37,712,087)
Depreciation and amortization		(1,906,164)	(1,796,383)
Reclassifications		(69,236)	(108,718)
Disposals		59,022	492,557
Ending balance		$ (41,041,009)	(39,124,631)	(37,712,087)
Buildings [member] | Bottom of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Depreciation rates	3.00%	3.00%
Estimated useful lives	33 Years	33 Years
Buildings [member] | Top of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Depreciation rates	7.00%	7.00%
Estimated useful lives	35 Years	35 Years
Offshore platforms [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		$ 169,542,435
Ending balance		$ 148,222,706	169,542,435
Depreciation rates	4.00%	4.00%
Estimated useful lives	25 Years	25 Years
Offshore platforms [member] | Gross carrying amount [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		$ 322,704,205	260,328,096
Acquisitions		7,811,374	9,866,984
Reclassifications		(10,199,213)
Capitalization		8,677,765	17,318,279
Impairment		(15,564,190)	35,640,491
Disposals			(449,645)
Ending balance		313,429,941	322,704,205	260,328,096
Offshore platforms [member] | Accumulated depreciation and amortization [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		(153,161,770)	(140,908,960)
Depreciation and amortization		(13,192,369)	(12,252,810)
Reclassifications		1,146,904
Ending balance		(165,207,235)	(153,161,770)	(140,908,960)
Furniture and equipment [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		13,756,021
Ending balance		12,084,714	13,756,021
Furniture and equipment [member] | Gross carrying amount [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		50,746,687	52,966,194
Acquisitions		1,183,679	545,271
Reclassifications		(96,899)	(561,569)
Capitalization		30,879	2,769
Impairment			438,979
Disposals		(806,694)	(2,644,957)
Ending balance		51,057,652	50,746,687	52,966,194
Furniture and equipment [member] | Accumulated depreciation and amortization [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		(36,990,666)	(36,513,479)
Depreciation and amortization		(2,890,563)	(3,205,089)
Reclassifications		102,375	166,914
Disposals		805,916	2,560,988
Ending balance		$ (38,972,938)	(36,990,666)	(36,513,479)
Furniture and equipment [member] | Bottom of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Depreciation rates	3.00%	3.00%
Estimated useful lives	3 Years	3 Years
Furniture and equipment [member] | Top of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Depreciation rates	10.00%	10.00%
Estimated useful lives	10 Years	10 Years
Transportation equipment [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		$ 13,526,082
Ending balance		16,453,330	13,526,082
Transportation equipment [member] | Gross carrying amount [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		19,442,845	15,329,095
Acquisitions		284,445	2,063,519
Reclassifications		(75,674)	(325,778)
Capitalization		3,746,395	2,918,621
Impairment			8,743
Disposals		(226,375)	(551,355)
Ending balance		23,171,636	19,442,845	15,329,095
Transportation equipment [member] | Accumulated depreciation and amortization [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		(5,916,763)	(5,894,520)
Depreciation and amortization		(1,038,839)	(1,027,289)
Reclassifications		14,532	454,492
Disposals		222,764	550,554
Ending balance		$ (6,718,306)	(5,916,763)	(5,894,520)
Transportation equipment [member] | Bottom of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Depreciation rates	4.00%	4.00%
Estimated useful lives	5 Years	5 Years
Transportation equipment [member] | Top of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Depreciation rates	20.00%	20.00%
Estimated useful lives	25 Years	25 Years
Construction in progress [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		$ 207,414,148
Ending balance		129,736,382	207,414,148
Construction in progress [member] | Gross carrying amount [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		207,414,148	211,675,597
Acquisitions		51,410,469	107,682,868
Reclassifications		(812,943)	(282,044)
Capitalization		(114,700,828)	(89,945,973)
Impairment		(6,849,534)	(16,852,238)
Disposals		(6,724,930)	(4,864,062)
Ending balance		129,736,382	207,414,148	211,675,597
Land [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		44,571,618
Ending balance		44,546,699	44,571,618
Land [member] | Gross carrying amount [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		44,571,618	43,347,802
Acquisitions		58,563	1,487,434
Reclassifications		(560)	50,709
Capitalization		29,248
Disposals		(112,170)	(314,327)
Ending balance		$ 44,546,699	44,571,618	43,347,802
Land [member] | Bottom of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Estimated useful lives	-	-
Unproductive fixed assets [member] | Gross carrying amount [member]
Disclosure of detailed information about property, plant and equipment [line items]
Acquisitions			6,800
Reclassifications			2,039
Disposals			(8,839)
Other Fixed Assets [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		$ 491,506
Ending balance		118,651	491,506
Other Fixed Assets [member] | Gross carrying amount [member]
Disclosure of detailed information about property, plant and equipment [line items]
Beginning balance		491,506	630,878
Reclassifications		4,072,464	(137,246)
Capitalization		(4,454)
Disposals		(4,440,865)	(2,126)
Ending balance		$ 118,651	$ 491,506	$ 630,878

XML

Wells, Pipelines, Properties, Plant and Equipment, Net - Detailed Information About Property, Plant and Equipment (Parenthetical) (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure of detailed information about property, plant and equipment [line items]
Financing cost capitalized to fixed assets	$ 5,945,638	$ 117,644,548	$ 98,844,464	$ 67,773,593
Depreciation and amortization		156,704,513	150,439,491	167,951,250
Plugging and abandonment cost		850,015	1,698,312	1,401,870
Provisions for plugging wells		68,797,600	64,967,710
Non-financial assets held for sale reclassified to fixed assets		4,652,314
Transfers from wells unassigned to a reserve		(16,440,645)	(16,393,773)
Net impairment		151,444,560
Net reversal of impairment			(331,314,343)
Pemex exploration and production [member]
Disclosure of detailed information about property, plant and equipment [line items]
Financing cost capitalized to fixed assets		$ 3,060,963	$ 3,667,752	$ 5,258,854

XML

Wells, Pipelines, Properties, Plant and Equipment, Net - Summary of Net Impairment (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure of detailed information about property, plant and equipment [line items]
Impairment		$ (155,244,350)	$ (19,640,505)
Reversal of impairment		3,799,790	350,954,848
Impairment / (Reversal of impairment)	$ (7,653,856)	(151,444,560)	331,314,343	$ (477,944,690)
Pemex exploration and production [member]
Disclosure of detailed information about property, plant and equipment [line items]
Impairment		(129,350,315)	(16,872,238)
Reversal of impairment			288,581,670
Impairment / (Reversal of impairment)		(129,350,315)	271,709,432
Pemex industrial transformation [member]
Disclosure of detailed information about property, plant and equipment [line items]
Impairment		(19,751,882)	(2,768,267)
Reversal of impairment		3,799,790	55,267,148
Impairment / (Reversal of impairment)		(15,952,092)	52,498,881
AGRO [member]
Disclosure of detailed information about property, plant and equipment [line items]
Impairment		(4,206,653)
Impairment / (Reversal of impairment)		(4,206,653)
Pemex Fertilizers [member]
Disclosure of detailed information about property, plant and equipment [line items]
Impairment		(1,935,500)
Impairment / (Reversal of impairment)		$ (1,935,500)
Pemex Logistics [member]
Disclosure of detailed information about property, plant and equipment [line items]
Reversal of impairment			5,829,520
Impairment / (Reversal of impairment)			5,829,520
Pemex Ethylene [member]
Disclosure of detailed information about property, plant and equipment [line items]
Reversal of impairment			1,276,510
Impairment / (Reversal of impairment)			$ 1,276,510

XML

Wells, Pipelines, Properties, Plant and Equipment, Net - Additional Information (Detail) $ in Thousands, $ in Thousands, Barrels_per_day in Millions			12 Months Ended
	Jul. 17, 2016 USD ($)	Jul. 08, 2016 USD ($)	Dec. 31, 2017 USD ($) Exchange_Rate	Dec. 31, 2017 MXN ($) Barrels_per_day Exchange_Rate	Dec. 31, 2016 MXN ($) Barrels_per_day Exchange_Rate	Dec. 31, 2015 MXN ($) Exchange_Rate
Disclosure of detailed information about property, plant and equipment [line items]
Impairment loss recognized				$ 155,244,350	$ 19,640,505
Net impairment			$ (7,653,856)	(151,444,560)	331,314,343	$ (477,944,690)
Net reversal of impairment				$ 3,799,790	350,954,848
Net reversal of impairment					(331,314,343)
Leases expire year			2018	2018
Leases expire on various dates			Over the next 10 years.	Over the next 10 years.
Capitalized interest expense from capital leases				$ 418,883	$ 500,654	$ 450,760
Discount rates on calculation of capitalized leases in nominal terms				7.96%	7.96%	7.96%
Discount rates on calculation of capitalized leases in real terms				1.11%	4.45%	5.71%
Total investment in contract				$ 45,230,000
Logistics [member]
Disclosure of detailed information about property, plant and equipment [line items]
Useful life					5 years
Value of proved asset					$ 139,436,715
Discount rate					12.63%
Two thousand seventeen to two thousand twenty one [member]
Disclosure of detailed information about property, plant and equipment [line items]
Total investment in contract				36,520,000
Pro Agroindustria S A [member]
Disclosure of detailed information about property, plant and equipment [line items]
Impairment loss recognized				4,206,653
Cash generating units of fertilizers [member]
Disclosure of detailed information about property, plant and equipment [line items]
Impairment loss recognized				1,935,500
Value of proved asset				$ 2,744,600
Discount rate			9.71%	9.71%
Network infrastructure [member]
Disclosure of detailed information about property, plant and equipment [line items]
Lease back agreements amount	$ 1,100,000	$ 600,000
Pemex exploration and production [member]
Disclosure of detailed information about property, plant and equipment [line items]
Impairment loss recognized				$ 129,350,315	$ 16,872,238
Appreciation rate				4.30%	20.10%
Foreign exchange rate | Exchange_Rate			19.7867	19.7867	20.6640	17.2065
Percentage of increase in discount rate			0.30%	0.30%
Percentage of decrease in crude oil price			7.20%	7.20%
Useful life			25 years	25 years	25 years
Production forecast | Barrels_per_day				7,091	7,092
Net impairment				$ (129,350,315)	$ 271,709,432
Net reversal of impairment					$ 288,581,670
Percentage of contractual area			100.00%	100.00%
Percentage of Production area			70.00%	70.00%
Percentage of contract behalf			33.3333%	33.3333%
Pemex exploration and production [member] | Bottom of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Useful lives of fixed assets					20 years
Pemex exploration and production [member] | Top of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Useful lives of fixed assets					25 years
Pemex exploration and production [member] | Licenses [member]
Disclosure of detailed information about property, plant and equipment [line items]
Percentage of contractual area			40.00%	40.00%
Pemex exploration and production [member] | Area two [member]
Disclosure of detailed information about property, plant and equipment [line items]
Percentage of Production area			30.00%	30.00%
Pemex exploration and production [member] | Area eight [member]
Disclosure of detailed information about property, plant and equipment [line items]
Percentage of contractual area			50.00%	50.00%
Pemex exploration and production [member] | Oil fields [member]
Disclosure of detailed information about property, plant and equipment [line items]
Net reversal of impairment					$ 288,581,670
Pemex industrial transformation [member]
Disclosure of detailed information about property, plant and equipment [line items]
Impairment loss recognized				$ 19,751,882	$ 2,768,267
Appreciation rate					20.10%
Foreign exchange rate | Exchange_Rate					20.6640	17.2065
Net impairment				(15,952,092)	$ 52,498,881
Net reversal of impairment				$ 3,799,790	55,267,148
Net reversal of impairment					$ 52,498,881
Pemex industrial transformation [member] | Bottom of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Discount rate					12.06%
Pemex industrial transformation [member] | Top of range [member]
Disclosure of detailed information about property, plant and equipment [line items]
Discount rate					13.72%
Pemex industrial transformation [member] | Refining [member]
Disclosure of detailed information about property, plant and equipment [line items]
Foreign exchange rate | Exchange_Rate			19.7867	19.7867
Percentage of decrease in discount rate			4.40%	4.40%
Discount rate			11.53%	11.53%
Pemex industrial transformation [member] | Gas [member]
Disclosure of detailed information about property, plant and equipment [line items]
Foreign exchange rate | Exchange_Rate			19.7867	19.7867	20.6640
Percentage of decrease in discount rate			4.50%	4.50%
Discount rate			10.24%	10.24%	10.72%
Pemex industrial transformation [member] | Petrochemicals [member]
Disclosure of detailed information about property, plant and equipment [line items]
Foreign exchange rate | Exchange_Rate			19.7867	19.7867		20.6640
Percentage of decrease in discount rate			5.60%	5.60%
Discount rate			9.71%	9.71%		10.29%
Pemex industrial transformation [member] | Matapionche Processor Center [member]
Disclosure of detailed information about property, plant and equipment [line items]
Impairment loss recognized					$ 65,105
Pemex industrial transformation [member] | Cangrejera Petrochemical Center [member]
Disclosure of detailed information about property, plant and equipment [line items]
Impairment loss recognized					2,590,870
Net reversal of impairment				$ 3,565,355
Pemex industrial transformation [member] | Independencia Petrochemical Center [member]
Disclosure of detailed information about property, plant and equipment [line items]
Impairment loss recognized					112,292
Net reversal of impairment				112,292
Pemex industrial transformation [member] | Arenque gas processor complex [member]
Disclosure of detailed information about property, plant and equipment [line items]
Net reversal of impairment				$ 57,039	268,161
Pemex Logistics [member]
Disclosure of detailed information about property, plant and equipment [line items]
Net impairment					5,829,520
Net reversal of impairment					5,829,520
Pemex Ethylene [member]
Disclosure of detailed information about property, plant and equipment [line items]
Net impairment					$ 1,276,510
Discount rate					10.29%
Net reversal of impairment					$ 1,276,510
BHP Billiton [member] | Licenses [member]
Disclosure of detailed information about property, plant and equipment [line items]
Percentage of contractual area			60.00%	60.00%
Chevron [member]
Disclosure of detailed information about property, plant and equipment [line items]
Percentage of contract behalf			33.3334%	33.3334%
Inpex [member]
Disclosure of detailed information about property, plant and equipment [line items]
Percentage of contract behalf			33.3333%	33.3333%

XML

Wells, Pipelines, Properties, Plant and Equipment, Net - Assumptions to Determine Net Present Value of Reserves Long Lived Assets (Detail)	12 Months Ended
	Dec. 31, 2017 USD ($) Exchange_Rate	Dec. 31, 2016 USD ($) Exchange_Rate	Dec. 31, 2015 Exchange_Rate	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)
Pemex industrial transformation [member]
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Rate of U.S. dollar | Exchange_Rate		20.6640	17.2065
Pemex exploration and production [member]
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Average crude oil price	$ 55.89	$ 60.24
Average gas price	4.92	4.69
Average condensates price	$ 38.33	$ 40.22
Discount rate	14.40%	14.36%
Refined Products [member] | Pemex industrial transformation [member]
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Average crude oil price		$ 52.30
Processed volume					$ 1,100
Useful lives of the cash generating units		Average of 14 years
Rate of U.S. dollar | Exchange_Rate		20.6640
Discount rate		12.06%
Period		2018-2034
Gas [member] | Pemex industrial transformation [member]
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Processed volume				$ 3,085	$ 3,085
Useful lives of the cash generating units	Average of 9 years	Average of 10 years
Rate of U.S. dollar | Exchange_Rate	19.7867	20.6640
Discount rate	10.24%	10.72%
Period	2018-2029	2018-2029
Petrochemicals [member] | Pemex industrial transformation [member]
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Useful lives of the cash generating units	Average of 6 years		Average of 4 years
Rate of U.S. dollar | Exchange_Rate	19.7867		20.6640
Discount rate	9.71%		10.29%
Period	2016-2024		2016-2024
Refining [member] | Pemex industrial transformation [member]
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Average crude oil price	$ 51.30
Processed volume				$ 767
Useful lives of the cash generating units	Average of 16 years
Rate of U.S. dollar | Exchange_Rate	19.7867
Discount rate	11.53%
Period	2018-2034

XML

Wells, pipelines, properties, plant and equipment, net - Summary of Impairment in Cash Generating Units (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Total impairment of assets		$ (155,244,350)	$ (19,640,505)
Net impairment	$ (7,653,856)	(151,444,560)	331,314,343	$ (477,944,690)
Arenque gas processor complex		3,799,790	350,954,848
Pemex industrial transformation [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Total impairment of assets		(19,751,882)	(2,768,267)
Net impairment		(15,952,092)	52,498,881
Arenque gas processor complex		3,799,790	55,267,148
Pemex industrial transformation [member] | Minatitln Refinery [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Total impairment of assets		(5,691,005)
Arenque gas processor complex			33,165,095
Pemex industrial transformation [member] | Madero refinery [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Total impairment of assets		(8,480,880)
Arenque gas processor complex			21,833,892
Pemex industrial transformation [member] | Arenque gas processor complex [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Arenque gas processor complex		57,039	268,161
Pemex industrial transformation [member] | Cangrejera Petrochemical Center [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Total impairment of assets			(2,590,870)
Arenque gas processor complex		3,565,355
Pemex industrial transformation [member] | Independencia Petrochemical Center [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Total impairment of assets			(112,292)
Arenque gas processor complex		112,292
Pemex industrial transformation [member] | Matapionche Petrochemical Center [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Total impairment of assets			$ (65,105)
Pemex industrial transformation [member] | Salina Cruz Refinery [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Total impairment of assets		(5,579,997)
Pemex industrial transformation [member] | Matapionche Gas Processor Complex [Member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Arenque gas processor complex		$ 65,104

XML

Wells, pipelines, properties, plant and equipment, net - Summary of Impairment or Reversal of Impairment of Fixed Assets (Detail) - Pemex industrial transformation [member] - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Impairment or reversal of impairment of fixed assets	$ 79,053,642	$ 119,069,595
Minatitln Refinery [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Impairment or reversal of impairment of fixed assets	32,531,925	43,856,284
Madero refinery [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Impairment or reversal of impairment of fixed assets	11,420,952	33,961,120
Salina Cruz Refinery [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Impairment or reversal of impairment of fixed assets	12,051,597	36,057,410
Cangrejera Petrochemical Center [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Impairment or reversal of impairment of fixed assets	17,544,825	2,441,686
Independencia Petrochemical Center [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Impairment or reversal of impairment of fixed assets	3,146,413	1,706,687
Arenque gas processor complex [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Impairment or reversal of impairment of fixed assets	1,283,201	473,499
Matapionche Gas Processor Complex [Member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Impairment or reversal of impairment of fixed assets	$ 1,074,729	$ 572,909

XML

Wells, Pipelines, Properties, Plant and Equipment, Net - Assets Acquired Through Capital Leases (Detail) - MXN ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Disclosure of acquisitions and disposals [Line Items]
Assets acquired through capital leases	$ 9,446,108	$ 9,867,883
Gross carrying amount [member]
Disclosure of acquisitions and disposals [Line Items]
Assets acquired through capital leases	11,142,197	11,142,197
Accumulated depreciation and amortization [member]
Disclosure of acquisitions and disposals [Line Items]
Assets acquired through capital leases	$ (1,696,089)	$ (1,274,314)

XML

Wells, Pipelines, Properties, Plant and Equipment, Net - Summary of Maturity Analysis of Finance Lease Payables (Detail) - Dec. 31, 2017 $ in Thousands, $ in Thousands	USD ($)	MXN ($)
Disclosure Of Maturity Analysis Of Finance Lease Payables [Line Items]
Finance lease payables	$ 444,540	$ 8,795,954
Less: short-term unaccrued interest	16,749	331,412
Less: long-term unaccrued interest	42,630	843,480
Total capital leases	385,161	7,621,062
Less: current portion of leases (excluding interest)	78,026	1,543,881
Total long-term capital leases	307,135	6,077,181
2017 [member]
Disclosure Of Maturity Analysis Of Finance Lease Payables [Line Items]
Finance lease payables	94,377	1,867,411
2018 [member]
Disclosure Of Maturity Analysis Of Finance Lease Payables [Line Items]
Finance lease payables	60,268	1,192,496
2019 [member]
Disclosure Of Maturity Analysis Of Finance Lease Payables [Line Items]
Finance lease payables	60,268	1,192,496
2020 [member]
Disclosure Of Maturity Analysis Of Finance Lease Payables [Line Items]
Finance lease payables	60,268	1,192,496
2021 [member]
Disclosure Of Maturity Analysis Of Finance Lease Payables [Line Items]
Finance lease payables	60,268	1,192,496
2022 and thereafter [member]
Disclosure Of Maturity Analysis Of Finance Lease Payables [Line Items]
Finance lease payables	$ 109,091	$ 2,158,559

XML

Wells, Pipelines, Properties, Plant and Equipment, Net - Consolidated and Separate Financial Statements (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2014 MXN ($)
Sales:
Net sales	$ 70,604,483	$ 1,397,029,719	$ 1,074,093,232	$ 1,161,760,392
Cost of sales	50,751,509	1,004,204,880	865,822,221	891,964,606
Gross income (loss)	12,199,118	241,380,279	539,585,354	(115,971,815)
Other income (loss), net	261,493	5,174,076	22,649,606	(875,487)
Administrative expenses	6,061,620	119,939,454	112,653,533	112,472,095
Operating income (loss)	5,292,708	104,725,231	424,350,187	(154,387,081)
Taxes, duties and other	(16,828,478)	(332,980,041)	(264,521,435)	(331,500,247)
Net income (loss)	(14,193,909)	(280,850,619)	$ (191,144,342)	(712,567,398)
Cash and cash equivalents	4,945,330			109,368,880	$ 97,851,754	$ 8,264,769	$ 163,532,513	$ 117,988,528
Accounts receivable	8,624,239				170,645,234		133,220,527
Total current assets	18,372,255			267,200,497	363,526,290		357,815,923
Wells, pipelines, properties, plant and equipment, net	72,599,743			1,344,483,631	1,436,509,326		1,667,742,248
Total assets	107,749,252			1,775,654,200	2,132,002,114		2,329,886,024
Suppliers	7,073,205				139,955,378		151,649,540
Taxes and duties payable	2,577,740				51,004,960		48,839,595
Total current liabilities	19,666,099			443,407,721	389,127,185		426,189,886
Total liabilities	183,676,636			3,107,330,098	3,634,354,499		3,562,894,171
Equity (deficit), net	$ (75,927,384)			$ (1,331,675,898)	(1,502,352,385)		$ (1,233,008,147)	$ (767,720,854)
Exploration and extraction contracts [member]
Sales:
Net sales		7,009,464
Cost of sales		5,459,264
Gross income (loss)		1,550,200
Other income (loss), net		4,852
Administrative expenses		34,338
Operating income (loss)		1,520,714
Taxes, duties and other		158,347
Net income (loss)		1,362,367
Cash and cash equivalents					45
Accounts receivable					3,144
Total current assets					3,189
Wells, pipelines, properties, plant and equipment, net					20,475,451
Total assets					20,478,640
Suppliers					796,300
Taxes and duties payable					973
Other current liabilities					8,569
Total current liabilities					805,842
Total liabilities					805,842
Equity (deficit), net					19,672,798
Exploration and extraction contracts [member] | Profit sharing [member] | EK or balam [member]
Sales:
Net sales		7,009,464
Cost of sales		5,447,955
Gross income (loss)		1,561,509
Other income (loss), net		4,852
Administrative expenses		34,338
Operating income (loss)		1,532,023
Taxes, duties and other		158,347
Net income (loss)		1,373,676
Wells, pipelines, properties, plant and equipment, net					14,869,906
Total assets					14,869,906
Suppliers					796,300
Taxes and duties payable					973
Other current liabilities					4,391
Total current liabilities					801,664
Total liabilities					801,664
Equity (deficit), net					14,068,242
Exploration and extraction contracts [member] | Profit sharing [member] | Block two [member]
Sales:
Cost of sales		5,953
Gross income (loss)		(5,953)
Operating income (loss)		(5,953)
Net income (loss)		(5,953)
Cash and cash equivalents					20
Accounts receivable					1,013
Total current assets					1,033
Total assets					1,033
Other current liabilities					1,809
Total current liabilities					1,809
Total liabilities					1,809
Equity (deficit), net					(776)
Exploration and extraction contracts [member] | Profit sharing [member] | Block eight [member]
Sales:
Cost of sales		4,845
Gross income (loss)		(4,845)
Operating income (loss)		(4,845)
Net income (loss)		(4,845)
Cash and cash equivalents					25
Accounts receivable					1,804
Total current assets					1,829
Total assets					1,829
Other current liabilities					2,369
Total current liabilities					2,369
Total liabilities					2,369
Equity (deficit), net					(540)
Exploration and extraction contracts [member] | license [member] | Trion [member]
Sales:
Wells, pipelines, properties, plant and equipment, net					4,498,234
Total assets					4,498,234
Equity (deficit), net					4,498,234
Exploration and extraction contracts [member] | license [member] | Block Three [member]
Sales:
Cost of sales		511
Gross income (loss)		(511)
Operating income (loss)		(511)
Net income (loss)		$ (511)
Accounts receivable					327
Total current assets					327
Wells, pipelines, properties, plant and equipment, net					1,107,311
Total assets					1,107,638
Equity (deficit), net					$ 1,107,638

XML

Intangible Assets - Additional Information (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of detailed information about intangible assets [abstract]
Intangible assets are wells unassigned	$ 9,088,563	$ 8,639,242	$ 14,304,961
Expenses related to unsuccessful wells	$ 2,500,638	$ 19,307,838

XML

Intangible Assets - Schedule of Intangible Assets are Wells Unassigned to a Reserve (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Wells unassigned to a reserve:
Balance at the beginning of period	$ 8,639,242	$ 14,304,961
Additions to construction in progress	20,553,952	20,526,300
Transfers against expenses	(3,663,986)	(9,798,246)
Transfers against fixed assets	(16,440,645)	(16,393,773)
Balance at the end of period	$ 9,088,563	$ 8,639,242

XML

Long-term Notes Receivable and Other Assets - Summary of Long-term Notes Receivable (Detail) - MXN ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Disclosure Of Notes Receivable And Other Long Term Assets [Abstract]
Promissory notes issued by the Mexican Government	$ 147,274,076	$ 140,578,871
Other long-term notes receivable	1,218,833	8,028,731
Total long-term notes receivable	$ 148,492,909	$ 148,607,602

XML

Long-term Notes Receivable and Other Assets - Summary of Promissory Notes Issued (Detail) - MXN ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Disclosure Of Notes Receivable And Other Long Term Assets [Abstract]
Total promissory notes	$ 149,796,282	$ 142,124,620
Less: current portion of notes receivable	2,522,206	1,545,749
Long-term promissory notes	$ 147,274,076	$ 140,578,871

XML

Long-term Notes Receivable and Other Assets - Additional Information (Detail) - MXN ($) $ in Thousands				1 Months Ended		12 Months Ended
	Aug. 15, 2016	Jun. 29, 2016	Dec. 24, 2015	Jun. 30, 2017	Aug. 15, 2016	Dec. 31, 2017	Dec. 31, 2016
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable						$ 147,274,076	$ 140,578,871
Promissory notes contibution amount						(2,522,206)	(1,545,749)
Financing income [member]
Disclosure of notes receivable and other non current assets [line items]
Accrued yields						$ 9,233,950	$ 3,597,654
Bottom of range [member]
Disclosure of notes receivable and other non current assets [line items]
Interest per annum of promissory notes						4.65%	4.35%
Top of range [member]
Disclosure of notes receivable and other non current assets [line items]
Interest per annum of promissory notes						7.03%	7.04%
Fondo laboral pemex portfolio [member]
Disclosure of notes receivable and other non current assets [line items]
Maturity				2017
Fondo laboral pemex portfolio [member] | Federal Government [member]
Disclosure of notes receivable and other non current assets [line items]
Remaining part of promissory note transferred						$ 22,217,300
2017 [member] | Fondo laboral pemex portfolio [member]
Disclosure of notes receivable and other non current assets [line items]
Promissory notes contibution amount				$ 1,562,288
SHCP [member]
Disclosure of notes receivable and other non current assets [line items]
Accrued interest rate			6.93%
Petroleos Mexicanos [member]
Disclosure of notes receivable and other non current assets [line items]
Notes issued in advance payment			$ 50,000,000
Discounted value of promissory note		$ 184,230,586
Promissory notes exchange price	$ 47,000,000
Increase in equity		$ 135,439,612
Increase in convertible promissory notes					$ 1,209,026
Non-negotiable promissory note [member] | SHCP [member]
Disclosure of notes receivable and other non current assets [line items]
Notes issued in advance payment			$ 50,000,000

XML

Long-term Notes Receivable and Other Assets - Summary of Promissory Notes Maturity Dates and Annual Rates (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2017 MXN ($) Promissory_Notes	Dec. 31, 2016 MXN ($) Promissory_Notes
Disclosure of notes receivable and other non current assets [line items]
Total promissory notes	$ 149,796,282	$ 142,124,620
Less: current portion	2,522,206	1,545,749
Long-term notes receivable	147,274,076	140,578,871
4.65% notes due 2018 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable	$ 2,522,206	$ 2,408,634
Number of Promissory Notes | Promissory_Notes	1	1
Maturity	2018	2018
Yield Rate Range	4.65%	4.65%
5.14% notes due 2019 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable	$ 3,580,302	$ 3,402,849
Number of Promissory Notes | Promissory_Notes	1	1
Maturity	2019	2019
Yield Rate Range	5.14%	5.14%
5.39% notes due 2020 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable	$ 4,421,320	$ 4,192,132
Number of Promissory Notes | Promissory_Notes	1	1
Maturity	2020	2020
Yield Rate Range	5.39%	5.39%
5.57% notes due 2021 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable	$ 5,238,081	$ 4,957,840
Number of Promissory Notes | Promissory_Notes	1	1
Maturity	2021	2021
Yield Rate Range	5.57%	5.57%
5.74% notes due 2022 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable	$ 5,804,485
Number of Promissory Notes | Promissory_Notes	1
Maturity	2022
Yield Rate Range	5.74%
5.87% notes and 6.32% notes due 2023 to 2027 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable	$ 34,196,434
Number of Promissory Notes | Promissory_Notes	5
Maturity	2023 to 2027
5.87% notes and 6.32% notes due 2023 to 2027 [member] | Bottom of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range	5.87%
5.87% notes and 6.32% notes due 2023 to 2027 [member] | Top of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range	6.32%
6.47% notes and 6.81% notes due 2028 to 2032 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable	$ 35,338,617
Number of Promissory Notes | Promissory_Notes	5
Maturity	2028 to 2032
6.47% notes and 6.81% notes due 2028 to 2032 [member] | Bottom of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range	6.47%
6.47% notes and 6.81% notes due 2028 to 2032 [member] | Top of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range	6.81%
6.85% notes and 7.03% notes due 2033 to 2037 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable	$ 32,789,697
Number of Promissory Notes | Promissory_Notes	5
Maturity	2033 to 2037
6.85% notes and 7.03% notes due 2033 to 2037 [member] | Bottom of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range	6.85%
6.85% notes and 7.03% notes due 2033 to 2037 [member] | Top of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range	7.03%
7.02% notes and 6.94% notes due 2038 to 2042 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable	$ 25,905,140
Number of Promissory Notes | Promissory_Notes	5
Maturity	2038 to 2042
7.02% notes and 6.94% notes due 2038 to 2042 [member] | Bottom of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range	7.02%
7.02% notes and 6.94% notes due 2038 to 2042 [member] | Top of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range	6.94%
4.35% notes due 2017 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable		$ 1,545,749
Number of Promissory Notes | Promissory_Notes		1
Maturity		2017
Yield Rate Range		4.35%
4.74% notes and 6.11% notes due 2022 to 2026 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable		$ 30,986,252
Number of Promissory Notes | Promissory_Notes		5
Maturity		2022 to 2026
4.74% notes and 6.11% notes due 2022 to 2026 [member] | Bottom of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range		4.74%
4.74% notes and 6.11% notes due 2022 to 2026 [member] | Top of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range		6.11%
6.32% and 6.77% notes due 2027 and 2031 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable		$ 33,280,216
Number of Promissory Notes | Promissory_Notes		5
Maturity		2027 to 2031
6.32% and 6.77% notes due 2027 and 2031 [member] | Bottom of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range		6.32%
6.32% and 6.77% notes due 2027 and 2031 [member] | Top of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range		6.77%
6.81% notes to 7% notes due 2032 to 2036 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable		$ 31,370,504
Number of Promissory Notes | Promissory_Notes		5
Maturity		2032 to 2036
6.81% notes to 7% notes due 2032 to 2036 [member] | Bottom of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range		6.81%
6.81% notes to 7% notes due 2032 to 2036 [member] | Top of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range		7.00%
6.94% and 7.04% notes due 2037 and 2042 [member]
Disclosure of notes receivable and other non current assets [line items]
Long-term notes receivable		$ 29,980,444
Number of Promissory Notes | Promissory_Notes		6
Maturity		2037 to 2042
6.94% and 7.04% notes due 2037 and 2042 [member] | Bottom of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range		6.94%
6.94% and 7.04% notes due 2037 and 2042 [member] | Top of range [member]
Disclosure of notes receivable and other non current assets [line items]
Yield Rate Range		7.04%

XML

Long-term Notes Receivable and Other Assets - Summary of Other Assets (Detail) $ in Thousands, $ in Thousands	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)
Disclosure Of Notes Receivable And Other Long Term Assets [Abstract]
Payments in advance		$ 4,683,117	$ 2,558,767
License		2,162,151	1,813,605
Rights-of-way		1,967,304	1,940,157
Other		2,672,605	3,200,116
Total other assets	$ 580,449	$ 11,485,177	$ 9,512,645

XML

Debt - Additional Information (Detail) € in Thousands, ¥ in Thousands, SFr in Thousands								1 Months Ended			12 Months Ended
	Dec. 21, 2017 USD ($)	Dec. 18, 2017 USD ($)	Dec. 15, 2017 USD ($)	Nov. 16, 2017 MXN ($)	Jul. 08, 2016 USD ($)	Jun. 17, 2016 USD ($)	Feb. 05, 2016 MXN ($)	Dec. 31, 2017 USD ($)	Jul. 17, 2017 USD ($)	May 15, 2017 USD ($)	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)	Feb. 18, 2018 USD ($)	Dec. 31, 2017 MXN ($)	Jul. 21, 2017 USD ($)	Jul. 18, 2017 USD ($)	Jul. 14, 2017 USD ($)	Jun. 16, 2017 USD ($)	Jun. 15, 2017 USD ($)	May 24, 2017 USD ($)	Feb. 14, 2017 EUR (€)	Dec. 31, 2016 USD ($)	Dec. 31, 2016 MXN ($)	Dec. 14, 2016 USD ($)	Dec. 13, 2016 USD ($)	Dec. 06, 2016 USD ($)	Nov. 17, 2016 USD ($)	Nov. 17, 2016 MXN ($)	Oct. 03, 2016 USD ($)	Sep. 21, 2016 USD ($)	Jul. 26, 2016 CNY (¥)	Jun. 14, 2016 CHF (SFr)	Apr. 19, 2016 EUR (€)	Mar. 28, 2016 MXN ($)	Mar. 23, 2016 MXN ($)	Mar. 17, 2016 MXN ($)	Mar. 15, 2016 USD ($)	Mar. 15, 2016 EUR (€)	Feb. 04, 2016 USD ($)	Jan. 25, 2016 USD ($)	Nov. 18, 2015 USD ($)	Nov. 18, 2015 MXN ($)
Disclosure of debt [Line Items]
Internal net debt																														$ 28,000,000,000														$ 110,500,000,000
External net debt																														7,100,000,000													$ 8,500,000,000
Total amount of net debt																													$ 8,055,900,000	$ 150,000,000,000													$ 15,722,000,000	$ 240,550,000,000
Debt securities issued															$ 4,000,000,000
Line of credit								$ 5,400,000,000			$ 5,400,000,000					$ 23,500,000,000								$ 4,630,000,000	$ 3,500,000,000
Principal amount of debt																2,001,742,870,000									1,948,366,564,000
Repayment of revolving credit lines											32,342,434,000	$ 642,059,819,000	$ 614,987,329,000	$ 193,618,498,000
Line of credit to ensure liquidity								$ 6,700,000,000			$ 6,700,000,000					$ 23,500,000,000								4,750,000,000	$ 23,500,000,000
Sale and leaseback of oil and gas products						$ 1,100,000,000
Lease agreement period						15 years
Sale and leaseback of oil and gas products												$ 762,637,362,000	$ 616,380,608,000	$ 690,591,455,000
Madero refinery [member]
Disclosure of debt [Line Items]
Lease agreement period					20 years
Sale and leaseback of oil and gas products					$ 600,000,000
Subsidiaries [member]
Disclosure of debt [Line Items]
Revolving credit facility amount																								11,369,800,000
Revolving credit amount outstanding																								$ 0
Revolving credit line [member]
Disclosure of debt [Line Items]
Disbursement amount received									$ 1,950,000,000
Series C medium term notes program [member]
Disclosure of debt [Line Items]
Debt securities issued																		$ 92,000,000,000
Fixed rate [member]
Disclosure of debt [Line Items]
Interest rate						8.38%																													5.11%
Line of credit | €																																			€ 500,000
Maturity date											March 2023	March 2023
Floating rate [member]
Disclosure of debt [Line Items]
Line of credit																										$ 300,000,000
Maturity date											December 2019	December 2019
Floating rate [member] | TIIE [member]
Disclosure of debt [Line Items]
Interest rate							0.55%
Maturity											March 2017	March 2017
Line of credit							$ 7,000,000,000,000																													$ 9,700,000,000
Maturity date							January 2017
Floating rate [member] | TIIE [member] | Certificados Bursatiles [member]
Disclosure of debt [Line Items]
Debt securities issued																																					$ 5,000,000,000
Maturity											October 2019	October 2019
Three point seven five percentage notes due two thousand twenty five [member]
Disclosure of debt [Line Items]
Debt securities issued				$ 450,000,000
Interest rate				3.75%
Maturity				2025
5.25% notes due April 6, 2024 [member] | Fixed rate [member] | Non-revolving credit facility [member]
Disclosure of debt [Line Items]
Interest rate								5.25%			5.25%					5.25%
Maturity								April 6, 2024
Line of credit								$ 132,000,000			$ 132,000,000
1.65 basis point due May 2020 [member] | Simple credit line [member]
Disclosure of debt [Line Items]
Maturity										May 2020
Line of credit										$ 400,000,000									$ 200,000,000			$ 200,000,000
Interest rate basis description										Floating interest rate linked to LIBOR plus 165 basis points
Interest rate										1.65%
6.50% notes due 2027 [member] | Series C medium term notes program [member]
Disclosure of debt [Line Items]
Debt securities issued																		$ 2,500,000,000
Interest rate																		6.50%
6.750% bonds due 2047 [member]
Disclosure of debt [Line Items]
Interest rate																															6.75%
Principal amount of debt																															$ 1,491,941,000
Principal amount of debt exchanged																															$ 8,059,000
6.750% bonds due 2047 [member] | Series C medium term notes program [member]
Disclosure of debt [Line Items]
Debt securities issued																		$ 2,500,000,000
Interest rate																		6.75%
5.750% note due to 2018 [member]
Disclosure of debt [Line Items]
Interest rate																	5.75%
Principal amount of debt purchased																	$ 922,485,000
3.500% notes due to 2018 [member]
Disclosure of debt [Line Items]
Interest rate																	3.50%
Principal amount of debt																	$ 644,374,000
3.125% notes due to 2019 [member]
Disclosure of debt [Line Items]
Interest rate																	3.125%
Principal amount of debt																	$ 172,591,000
One seven five basis point due two thousand twenty two [member] | Bilateral Credit Line [member]
Disclosure of debt [Line Items]
Maturity	2022
Line of credit	$ 300,000,000
Interest rate basis description	LIBOR plus 175 basis points
Interest rate	1.75%
8.000% notes due 2019 [member]
Disclosure of debt [Line Items]
Interest rate																															8.00%
Principal amount of debt purchased																															$ 687,725,000
5.750% notes due 2018 [member]
Disclosure of debt [Line Items]
Interest rate																															5.75%
Principal amount of debt purchased																															$ 657,050,000
Principal amount of debt exchanged																															$ 73,288,000
4.625% notes due 2023 [member]
Disclosure of debt [Line Items]
Interest rate																															4.625%
Principal amount of debt exchanged																															$ 69,302,000
5.500% bonds due 2044 [member]
Disclosure of debt [Line Items]
Interest rate																															5.50%
Principal amount of debt																															$ 1,591,961,000
Two five zero basis point due two thousand eighteen [member]
Disclosure of debt [Line Items]
Maturity			2018
Line of credit			$ 390,000,000
Interest rate basis description			LIBOR plus 250 basis points on a quarterly basis
Interest rate			2.50%
Line of credit prepaying amount			$ 140,000,000
Two five zero basis point due two thousand eighteen [member] | New Credit Line [member]
Disclosure of debt [Line Items]
Line of credit			$ 250,000,000
One six five basis point due two thousand twenty [member] | Bilateral Credit Line [member]
Disclosure of debt [Line Items]
Maturity		2020
Line of credit		$ 200,000,000
Interest rate basis description		LIBOR plus 165 basis points
Interest rate		1.65%
P.M.I. Holdings, B.V. [member]
Disclosure of debt [Line Items]
Revolving credit facility amount								15,141,500,000			15,141,500,000
Repayment of revolving credit lines											14,914,000,000
Revolving credit amount outstanding								$ 227,500,000			$ 227,500,000
Bottom of range [member]
Disclosure of debt [Line Items]
Debt securities issued																												$ 62,000,000,000
Bottom of range [member] | Floating rate [member] | TIIE [member]
Disclosure of debt [Line Items]
Line of credit																																						$ 2,000,000,000
Top of range [member]
Disclosure of debt [Line Items]
Debt securities issued																												$ 72,000,000,000
Top of range [member] | Floating rate [member] | TIIE [member]
Disclosure of debt [Line Items]
Line of credit																																						$ 3,300,000,000
Series C medium term notes program [member]
Disclosure of debt [Line Items]
Debt securities issued															$ 92,000,000,000					$ 92,000,000,000	$ 72,000,000,000		€ 4,250,000				$ 5,500,000,000					$ 62,000,000,000		SFr 375,000					$ 62,000,000,000	€ 2,250,000	$ 5,000,000,000
Principal amount of debt																																4,000,000,000
Series C medium term notes program [member] | Three point seven five percentage notes due two thousand twenty five [member]
Disclosure of debt [Line Items]
Debt securities issued				$ 92,000,000,000
Series C medium term notes program [member] | 1.50% notes due to June 2018 [member]
Disclosure of debt [Line Items]
Debt securities issued | SFr																																		SFr 225,000
Interest rate																																		1.50%
Maturity											June 2018	June 2018
Series C medium term notes program [member] | 2.35% notes due to December 2021 [member]
Disclosure of debt [Line Items]
Debt securities issued | SFr																																		SFr 150,000
Interest rate																																		2.35%
Maturity											December 2021	December 2021
Series C medium term notes program [member] | 4.625% notes due to September 2023 [member]
Disclosure of debt [Line Items]
Debt securities issued																																$ 2,000,000,000
Interest rate																																4.625%
Maturity											September 2023	September 2023
Series C medium term notes program [member] | 6.750% bonds due to September 2047 [member]
Disclosure of debt [Line Items]
Debt securities issued																																$ 2,000,000,000
Interest rate																																6.75%
Maturity											September 2047	September 2047
Series C medium term notes program [member] | 2.50% notes due August 2021 [member]
Disclosure of debt [Line Items]
Debt securities issued | €																							€ 1,750,000
Interest rate																							2.50%
Maturity											August 2021	August 2021
Series C medium term notes program [member] | 3.75% notes due February 2024 [member]
Disclosure of debt [Line Items]
Debt securities issued | €																							€ 1,250,000
Interest rate																							3.75%
Maturity											February 2024	February 2024
Series C medium term notes program [member] | 4.875% notes due February 2028 [member]
Disclosure of debt [Line Items]
Debt securities issued | €																							€ 1,250,000
Interest rate																							4.875%
Maturity											February 2028	February 2028
Series C medium term notes program [member] | 5.500% notes due February 2019 [member]
Disclosure of debt [Line Items]
Debt securities issued																																									$ 750,000,000
Interest rate																																									5.50%
Maturity											February 2019	February 2019
Series C medium term notes program [member] | 6.375% notes due February 2021 [member]
Disclosure of debt [Line Items]
Debt securities issued																																									$ 1,250,000,000
Interest rate																																									6.375%
Maturity											February 2021	February 2021
Series C medium term notes program [member] | 6.875% notes due August 2026 [member]
Disclosure of debt [Line Items]
Debt securities issued																																									$ 3,000,000,000
Interest rate																																									6.875%
Maturity											August 2026	August 2026
Series C medium term notes program [member] | 3.750% Notes due to March 2019 [member]
Disclosure of debt [Line Items]
Debt securities issued | €																																								€ 1,350,000
Interest rate																																							3.75%	3.75%
Maturity											March 2019	March 2019
Series C medium term notes program [member] | 5.125% Notes due to March 2023 [member]
Disclosure of debt [Line Items]
Debt securities issued | €																																								€ 900,000
Interest rate																																							5.125%	5.125%
Maturity											March 2023	March 2023
Series C medium term notes program [member] | 6.50% due March 2027 [member] | Fixed rate [member]
Disclosure of debt [Line Items]
Debt securities issued																											$ 3,000,000,000
Interest rate																											6.50%
Maturity											March 2027	March 2027
Series C medium term notes program [member] | 5.375% due March 2022 [member] | Fixed rate [member]
Disclosure of debt [Line Items]
Debt securities issued																											$ 1,500,000,000
Interest rate																											5.375%
Series C medium term notes program [member] | Notes due March 2022 [member] | Floating rate [member]
Disclosure of debt [Line Items]
Debt securities issued																											$ 1,000,000,000
Maturity											March 2022	March 2022
Series C medium term notes program [member] | Bottom of range [member]
Disclosure of debt [Line Items]
Debt securities issued																																										$ 52,000,000,000
Series C medium term notes program [member] | Top of range [member]
Disclosure of debt [Line Items]
Debt securities issued																																										$ 62,000,000,000
Bond securities [member]
Disclosure of debt [Line Items]
Debt securities issued | ¥																																	¥ 80,000,000
Interest rate																																	0.54%
Maturity											July 2026	July 2026

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Debt - Summary of Long-term Debt (Detail) € in Thousands, ¥ in Thousands, $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2017 EUR (€)	Dec. 31, 2017 JPY (¥)	Dec. 31, 2016 MXN ($)	Dec. 31, 2016 EUR (€)	Dec. 31, 2016 JPY (¥)	Dec. 31, 2015 MXN ($)
Disclosure of detailed information about borrowings [line items]
Total principal in pesos			$ 2,001,742,870			$ 1,948,366,564
Plus: accrued interest			32,078,624			27,815,467
Notes payable to contractors			4,053,577			6,988,699
Total			2,037,875,071			1,983,170,730
Less: short-term maturities			122,957,558			144,169,619
Current portion of notes payable to contractors			2,173,285			4,181,102
Accrued interest			32,078,624			27,815,467
Total short-term debt and current portion of long-term debt						176,166,188
Borrowings	$ 95,046,956		1,880,665,604			1,807,004,542			$ 1,300,873,167
Certificados Bursatiles [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	Zero rate and Fixed at 3.02% to 5.23%	Zero rate and Fixed at 3.02% to 5.23%
Maturity	Various to 2035	Various to 2035
Borrowings			57,197,211			53,703,421
U.S [member]
Disclosure of detailed information about borrowings [line items]
Borrowings	$ 68,519,829	$ 64,951,144	1,355,781,294			1,342,150,436
U.S [member] | Bonds [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	Fixed from 1.7% to 9.5% and LIBOR plus 0.35% to 3.65%	Fixed from 3.125% to 9.5% and LIBOR plus 0.35% to 2.02%
Maturity	Various to 2047	Various to 2046
Borrowings	$ 57,556,097	$ 54,751,738	1,138,845,231			1,131,389,914
U.S [member] | Purchasing loans [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	LIBOR plus 0.85%	LIBOR plus 0.8% to 0.85%
Maturity	Various to 2018	Various to 2016
Borrowings	$ 1,300,000	$ 120,000	25,722,710			2,479,680
U.S [member] | Project Finance [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	Fixed from 2.35% to 3.81% and LIBOR plus 0.24% to 1.75%	Fixed from 2.35% to 5.45% and LIBOR plus 0.01% to 1.71%
Maturity	Various to 2025	Various to 2021
Borrowings	$ 3,283,741	$ 4,099,481	64,974,389			84,711,684
U.S [member] | Direct loans [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	Fixed from 5.25% to 5.44% and LIBOR plus 1.65%	Fixed at 5.44% and LIBOR plus 1.0%
Maturity	Various to 2020	Various to 2018
Borrowings	$ 2,180,315	$ 1,601,848	43,141,231			33,100,587
U.S [member] | Syndicated loan [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	LIBOR plus 0.85%	LIBOR plus 0.85%
Maturity	Various to 2020	Various to 2020
Borrowings	$ 1,988,597	$ 1,986,865	39,347,774			41,056,571
U.S [member] | Bank loans [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	Fixed from 3.5% to 5.28%	Fixed from 3.5% to 5.28%
Maturity	Various to 2023	Various to 2023
Borrowings	$ 174,442	$ 210,019	3,451,629			4,339,826
U.S [member] | Finance Lease [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	Fixed from 0.38% to 1.99%	Fixed from 0.38% to 1.99%
Maturity	Various to 2025	Various to 2025
Borrowings	$ 385,161	$ 462,595	7,621,062			9,559,060
U.S [member] | Lease-back [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	Fixed from 0.45% to 0.7%	Fixed from 0.45% to 0.7%
Maturity	Various to 2036	Various to 2036
Borrowings	$ 1,651,476	$ 1,718,598	32,677,268			35,513,114
EURO [member]
Disclosure of detailed information about borrowings [line items]
Borrowings			299,265,574	€ 12,598,056		207,153,216	€ 9,558,388
EURO [member] | Bonds [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	Fixed from 1.875% to 5.5%	Fixed from 3.125% to 6.375%
Maturity	Various to 2030	Various to 2030
Borrowings			287,386,195	12,097,975		196,317,016	9,058,388
EURO [member] | Project Finance [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	Fixed from 2.1% to 5.11%	Fixed at 2%
Maturity	Various to 2023	Various to 2016
Borrowings			11,879,379	€ 500,081		10,836,200	€ 500,000
Japan, Yen [member]
Disclosure of detailed information about borrowings [line items]
Borrowings						31,318,032		¥ 176,728,356
Japan, Yen [member] | Bonds [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	Fixed from 0.54% to 3.5% and LIBOR yen plus 0.75%	Fixed at 3.5% and LIBOR yen plus 0.75%
Maturity	Various to 2026	Various to 2023
Borrowings			30,541,407		¥ 173,827,018	30,800,746		173,809,300
Japan, Yen [member] | Project Finance [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest		Fixed at 1.56% and Prime Rate yen plus 2.56%
Maturity		Various to 2017
Borrowings						517,286		¥ 2,919,056
Mexico, Pesos [member]
Disclosure of detailed information about borrowings [line items]
Borrowings			211,808,448			277,254,794
Mexico, Pesos [member] | Direct loans [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	Fixed at 6.55% and TIIE plus 0.85% to 1.25%	Fixed at 6.55% and TIIE plus 0.55% to 1.25%
Maturity	Various to 2025	Various to 2025
Borrowings			28,597,423			45,563,848
Mexico, Pesos [member] | Syndicated loan [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	TIIE plus 0.95	TIIE plus 0.95
Maturity	Various to 2025	Various to 2025
Borrowings			33,646,107			38,538,961
Mexico, Pesos [member] | Certificados Bursatiles [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	Mexican Government Treasury Certificates ("Cetes") , TIIE(1) less 0.06% to 1.35%, and fixed at 7.19% to 9.1%	Mexican Government Treasury Certificates ("Cetes") , TIIE(1) less 0.06% to 0.35%, and fixed at 7.19% to 9.15%
Maturity	Various to 2026	Various to 2026
Borrowings			149,564,918			173,151,985
Mexico, Pesos [member] | Revolved loans [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest		TIIE plus 0.55
Maturity		To 2016
Borrowings						20,000,000
Other Currencies [member] | Bonds [member]
Disclosure of detailed information about borrowings [line items]
Rate of interest	Fixed from 1.5% to 8.25%	Fixed from 2.5% to 8.25%
Maturity	Various to 2025	Various to 2022
Borrowings			$ 47,148,936			$ 36,786,665

XML

Debt - Summary of Long-term Debt (Parenthetical) (Detail) - MXN ($) $ in Thousands	1 Months Ended		3 Months Ended		6 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016
Disclosure of detailed information about borrowings [line items]
Loan from foreign banks	$ 1,701,363,406	$ 1,600,968,832	$ 1,701,363,406	$ 1,600,968,832	$ 1,701,363,406	$ 1,600,968,832
LIBOR [member]
Disclosure of detailed information about borrowings [line items]
Interest rates			1.69428%	0.99789%	1.83707%	1.31767%
TIIE Rate [member]
Disclosure of detailed information about borrowings [line items]
Interest rates	7.6241%	6.1066%	7.6556%	6.1875%
Cetes Rate [member]
Disclosure of detailed information about borrowings [line items]
Interest rates	7.22%	5.69%	7.36%	5.96%	7.53%	6.09%

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Debt - Summary of Notes Payable to Contractors (Detail) - MXN ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Disclosure Of Changes In Consolidated Debt [Abstract]
Total notes payable to contractors	$ 4,053,577	$ 6,988,699
Less: current portion of notes payable to contractors	2,173,285	4,181,102
Notes payable to contractors (long-term)	$ 1,880,292	$ 2,807,597

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Debt - Summary of Notes Payable to Contractors (Parenthetical) (Detail) $ in Thousands, $ in Thousands	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2016 MXN ($)
Disclosure Of Changes In Consolidated Debt [Line Items]
Notes payable outstanding		$ 1,678,843		$ 3,986,565
Floating Production Storage And Offloading [member]
Disclosure Of Changes In Consolidated Debt [Line Items]
Investment	$ 723,575
Outstanding balances owed to contractor	$ 120,017	$ 2,374,734	$ 145,283	$ 3,002,134

XML

Debt - Summary of Estimated Future Contract Payments (Detail) - Floating Production Storage And Offloading [member] $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)
Disclosure Of Estimated Future Contract Payments [Line Items]
2018	$ 25,267
2019	25,267
2020	25,267
2021	25,267
2022	18,949
Total	$ 120,017

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Debt - Summary of Outstanding Liability Transaction Payable (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 USD ($)
Outstanding Liability Transaction Payable [Abstract]
2018	$ 3,957,317	$ 199,999
2019	3,886,037	196,396
2020	3,886,037	196,396
2021	3,886,037	196,396
2022	3,886,037	196,396
2023 and thereafter	39,450,325	1,993,781
Total	58,951,790	2,979,364
Less: short-term unaccrued interest	2,399,475	121,267
Less: long-term unaccrued interest	23,875,047	1,206,621
Total financing	32,677,268	1,651,476
Less: short-term portion of financing (excluding interest)	1,557,842	78,732
Total long term financing	$ 31,119,426	$ 1,572,744

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Debt - Summary of Foreign Currency Translation (Detail) - MXN ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
U.S. dollars [member]
Disclosure Of Foreign Currency Translation [Line Items]
Exchange rate	$ 19.7867	$ 20.6640
Japanese yen [member]
Disclosure Of Foreign Currency Translation [Line Items]
Exchange rate	0.1757	0.1772
Pounds Sterling [member]
Disclosure Of Foreign Currency Translation [Line Items]
Exchange rate	26.7724	25.3051
Euro [member]
Disclosure Of Foreign Currency Translation [Line Items]
Exchange rate	23.7549	21.6724
Swiss Francs [member]
Disclosure Of Foreign Currency Translation [Line Items]
Exchange rate	20.2992	20.1974
Canadian dollar [member]
Disclosure Of Foreign Currency Translation [Line Items]
Exchange rate	15.7858	15.2896
Australian Dollar [member]
Disclosure Of Foreign Currency Translation [Line Items]
Exchange rate	$ 15.4752	$ 14.8842

XML

Debt - Summary of Maturities of Long Term Debt Principal Outstanding and Accrued Interest (Detail) - MXN ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Disclosure of detailed information about borrowings [abstract]
2018	$ 157,209,467
2019	159,403,397
2020	209,915,748
2021	185,307,669
2022	158,761,145
2023 and thereafter	1,167,277,645
Total	$ 2,037,875,071	$ 1,983,170,730

XML

Debt - Summary of Changes in Consolidated Debt (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Disclosure Of Changes In Consolidated Debt [Line Items]
Accrued interest	$ 32,078,624	$ 27,815,467
Financed public works contracts [member]
Disclosure Of Changes In Consolidated Debt [Line Items]
Changes in total debt: At the beginning of the year	1,983,170,730	1,493,381,835
Loans obtained-financing institutions	704,715,468	829,579,084
Loans obtained-financing lease		21,924,053
Debt payments	(642,059,819)	(614,987,329)
Interest paid	(108,910,417)	(88,757,428)
Foreign exchange	(16,685,439)	243,182,764
Accrued interest	117,644,548	98,847,751
At the end of the year	$ 2,037,875,071	$ 1,983,170,730

XML

Derivative Financial Instruments - Additional Information (Detail) € in Thousands		9 Months Ended	12 Months Ended
	Dec. 31, 2017 USD ($) $ / $ Agreement	Apr. 30, 2017 USD ($)	Dec. 31, 2017 USD ($) $ / $ Exchange_Rate Agreement	Dec. 31, 2017 MXN ($) Exchange_Rate	Dec. 31, 2016 MXN ($) Exchange_Rate	Dec. 31, 2015 MXN ($) Exchange_Rate	Jan. 31, 2021 USD ($)	Feb. 29, 2020 USD ($)	Dec. 31, 2019 USD ($)	Nov. 30, 2019 MXN ($)	Jun. 30, 2019 MXN ($)	Dec. 31, 2017 MXN ($) $ / $ Agreement	Dec. 31, 2017 EUR (€) $ / $ Agreement	Dec. 31, 2016 USD ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2016 JPY (¥)	Dec. 31, 2014
Disclosure of detailed information about financial instruments [line items]
Notional amount of debt issued	$ 6,700,000,000		$ 6,700,000,000									$ 23,500,000,000
Currency exchange rate | $ / $	19.7867		19.7867									19.7867	19.7867
Net foreign exchange loss			$ (1,171,702,000)	$ (23,184,122,000)	$ 254,012,743,000	$ 154,765,574,000
Percentage of company's total financial assets may be denominated in a currency other than its functional currency			5.00%	5.00%
Confidence level percentage			95.00%	95.00%
Net income			$ (14,193,909,000)	$ (280,850,619,000)	$ (191,144,342,000)	$ (712,567,398,000)
Increase decrease in exchange rate			10.00%	10.00%	10.00%	10.00%
Increase in occurs of crude oil hedge			$ 0
Notes, face value												$ 2,001,742,870,000			$ 1,948,366,564,000
Preserve a cash balance at suitable level			$ 3,000,000,000
Net fair value of derivative financial instruments												12,367,475,000			(26,010,486,000)
Derivative financial instruments designated as hedges												$ 0			$ 0
Net gain (loss) of derivative financial instrument				$ 25,338,324,000	$ (14,000,987,000)	$ (21,449,877,000)
Increase [member]
Disclosure of detailed information about financial instruments [line items]
Net income				149,669,000	124,512,000	105,915,000
Decrease [member]
Disclosure of detailed information about financial instruments [line items]
Net income				$ 149,669,000	$ 124,512,000	$ 105,915,000
EURO [member]
Disclosure of detailed information about financial instruments [line items]
Currency exchange rate	23.7549		23.7549									23.7549	23.7549	21.6724	21.6724	21.6724
Us Dollar [member]
Disclosure of detailed information about financial instruments [line items]
Average foreign exchange rate | Exchange_Rate			19.7867	19.7867	20.6640
Euro [member]
Disclosure of detailed information about financial instruments [line items]
Average foreign exchange rate | Exchange_Rate			23.7549	23.7549	21.6724
Japan, Yen [member]
Disclosure of detailed information about financial instruments [line items]
Currency exchange rate	0.1757		0.1757									0.1757	0.1757	0.17721	0.17721	0.17721
Top of range [member]
Disclosure of detailed information about financial instruments [line items]
Liquidity risk mitigation amount through syndicated credit lines				$ 700,000,000
Liquidity risk mitigation amount through bilateral credit lines				$ 650,000,000
P.M.I. Norteamrica, S. A. de C. V. [member]
Disclosure of detailed information about financial instruments [line items]
Note maturity period			Dec. 31, 2017	Dec. 31, 2017
Maturity period			June 2016	June 2016
Notes, face value	$ 108,000		$ 108,000
Investment in structured notes			$ 0
P.M.I. Holdings, B.V. [member]
Disclosure of detailed information about financial instruments [line items]
DFIs and debt portfolio to parallel shift basis points			10	10
Assumption of either an increase or decrease of basis points in floating interest rates of debt and corresponding hedges			25.00%	25.00%	25.00%	25.00%
Percentage of increase of DFIs and debt portfolio to exchange rates of currencies against the U.S. dollar			1.00%	1.00%
P.M.I. Holdings, B.V. [member] | Twenty five basis points higher [member]
Disclosure of detailed information about financial instruments [line items]
Net income				$ 704,011,000	$ 841,024,000	$ 922,268,000
P.M.I. Holdings, B.V. [member] | Twenty five basis points lower [member]
Disclosure of detailed information about financial instruments [line items]
Net income				$ 704,011,000	$ 841,024,000	$ 922,268,000
PMI Trading Ltd [member]
Disclosure of detailed information about financial instruments [line items]
Confidence level percentage			99.00%	99.00%
VaR recorded	(8,789)		$ (8,789)											$ (23,198)
PMI Trading Ltd [member] | Top of range [member]
Disclosure of detailed information about financial instruments [line items]
VaR recorded	(19,695)		(19,695)
PMI Trading Ltd [member] | Bottom of range [member]
Disclosure of detailed information about financial instruments [line items]
VaR recorded	(4,720)		$ (4,720)
Pemex industrial transformation [member]
Disclosure of detailed information about financial instruments [line items]
Average foreign exchange rate | Exchange_Rate					20.6640	17.2065
Percent of overdue accounts over total sales			1.00%	1.00%
Pemex industrial transformation [member] | Exempted credit line [member]
Disclosure of detailed information about financial instruments [line items]
Fair value for client with credit lines			$ 1,464
Amount of credit lines	117,956		$ 117,956
Percentage of available credit lines			1.00%	1.00%
Pemex industrial transformation [member] | Guaranteed credit line [member]
Disclosure of detailed information about financial instruments [line items]
Fair value for client with credit lines			$ 8,183
Amount of credit lines	930,199		$ 930,199
Percentage of available credit lines			1.00%	1.00%
Cross - currency swaps [member] | P.M.I. Norteamrica, S. A. de C. V. [member]
Disclosure of detailed information about financial instruments [line items]
Notional amount of debt issued	$ 450,000,000		$ 450,000,000
Seagull option [member] | P.M.I. Norteamrica, S. A. de C. V. [member]
Disclosure of detailed information about financial instruments [line items]
Notional amount of debt issued													€ 4,250,000			¥ 80,000,000
Annual coupon rate														0.50%	0.50%	0.50%
Currency exchange rate	19.7867		19.7867			17.2065						19.7867	19.7867	20.6640	20.6640	20.6640	14.7180
Average foreign exchange rate | Exchange_Rate			117.39	117.39
Net foreign exchange loss				$ 23,184,122,000	$ (254,012,743,000)	$ (154,765,574,000)
Proportion of net foreign exchange loss			89.40%	89.40%
Seagull option [member] | P.M.I. Norteamrica, S. A. de C. V. [member] | Debt securities [member]
Disclosure of detailed information about financial instruments [line items]
Net foreign exchange loss				$ 16,685,439,000	$ (243,182,764,000)	$ (152,554,454,000)
Seagull option [member] | P.M.I. Norteamrica, S. A. de C. V. [member] | Japan, Yen [member]
Disclosure of detailed information about financial instruments [line items]
Currency exchange rate	75.0000		75.0000									75.0000	75.0000	83.7000	83.7000	83.7000
Peso teasury portfolio [member] | P.M.I. Holdings, B.V. [member]
Disclosure of detailed information about financial instruments [line items]
Investment in Portfolio				(10,820)
Fondo laboral pemex portfolio [member] | P.M.I. Holdings, B.V. [member]
Disclosure of detailed information about financial instruments [line items]
Investment in Portfolio				(44,950)
Fideicomiso de Cobertura Laboral y de Vivienda Portfolio [member] | P.M.I. Holdings, B.V. [member]
Disclosure of detailed information about financial instruments [line items]
Investment in Portfolio				(7,170)
U.S. Dollar Treasury Portfolio [member] | P.M.I. Holdings, B.V. [member]
Disclosure of detailed information about financial instruments [line items]
Investment in Portfolio			$ 0	$ (544,320)
Interest rate risk [member] | Interest rate swaps [member] | P.M.I. Norteamrica, S. A. de C. V. [member]
Disclosure of detailed information about financial instruments [line items]
Aggregate notional amount	$ 71,936		$ 71,936
Interest rate of derivative instrument	4.17%		4.17%									4.17%	4.17%
Weighted average term of derivative instrument	4 years 4 months 28 days
Exchange rate risk [member] | Extinguishing swap [member] | P.M.I. Norteamrica, S. A. de C. V. [member]
Disclosure of detailed information about financial instruments [line items]
Aggregate notional amount	$ 1,146,410,000		$ 1,146,410,000
Twenty day delta gamma risk analysis [member]
Disclosure of detailed information about financial instruments [line items]
Confidence level percentage			95.00%	95.00%
Number of observations			500	500
Risk expiring in june two thousand and nineteen [member] | P.M.I. Norteamrica, S. A. de C. V. [member]
Disclosure of detailed information about financial instruments [line items]
Revolving credit committed to mitigate liquidity risk							$ 1,950,000,000	$ 3,250,000,000	$ 1,500,000,000	$ 20,000,000,000	$ 3,500,000,000
Equity price risk [member]
Disclosure of detailed information about financial instruments [line items]
Number of barrels hedged		409,000	440,000	440,000
Amount of barrels hedged	449,898,000	133,503,000	449,898,000									449,898,000	449,898,000
Income from hedged		$ 205,705,000
PEMEX [member] | Interest rate risk [member]
Disclosure of detailed information about financial instruments [line items]
Total net debt outstanding consisted of floating rate debt	15.60%
PEMEX [member] | Interest rate risk [member] | Interest rate swaps [member]
Disclosure of detailed information about financial instruments [line items]
Number of interest rate swap agreements | Agreement	4		4									4	4
Aggregate notional amount	$ 1,623,750		$ 1,623,750
Interest rate of derivative instrument	2.35%		2.35%									2.35%	2.35%
Weighted average term of derivative instrument	7 years 11 days
PEMEX [member] | Exchange rate risk [member] | Cross - currency swaps [member] | P.M.I. Norteamrica, S. A. de C. V. [member] | Philippines, Pesos [member]
Disclosure of detailed information about financial instruments [line items]
Aggregate notional amount												$ 6,291,969,000
PEMEX [member] | Exchange rate risk [member] | Inflation risk [member] | P.M.I. Norteamrica, S. A. de C. V. [member] | EURO [member]
Disclosure of detailed information about financial instruments [line items]
Aggregate notional amount														$ 3,459,236,000
PEMEX [member] | Exchange rate risk [member] | Inflation risk [member] | P.M.I. Norteamrica, S. A. de C. V. [member] | Philippines, Pesos [member]
Disclosure of detailed information about financial instruments [line items]
Aggregate notional amount															$ 1,077,101,000

XML

Derivative Financial Instruments - Details of Interest rate sensitivity (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)
Switzerland, Francs [member]
Derivative Financial Instruments [line items]
Sensitivity debt	$ 3,144
Sensitivity DFIs	(3,144)
PEMEX Curves Sensitivity debt	3,030
EURO [member]
Derivative Financial Instruments [line items]
Sensitivity debt	100,081
Sensitivity DFIs	(84,962)
Sensitivity net	15,119
PEMEX Curves Sensitivity debt	82,839
Pound sterling [member]
Derivative Financial Instruments [line items]
Sensitivity debt	7,691
Sensitivity DFIs	(7,073)
Sensitivity net	618
PEMEX Curves Sensitivity debt	6,587
Japan, Yen [member]
Derivative Financial Instruments [line items]
Sensitivity debt	8,542
Sensitivity DFIs	(3,972)
Sensitivity net	4,570
PEMEX Curves Sensitivity debt	6,877
Mexico, Pesos [member]
Derivative Financial Instruments [line items]
Sensitivity debt	43,774
Sensitivity DFIs	2,039
Sensitivity net	45,813
PEMEX Curves Sensitivity debt	42,012
Mexican Unidad de Inversion [member]
Derivative Financial Instruments [line items]
Sensitivity debt	16,496
Sensitivity DFIs	(11,586)
Sensitivity net	4,910
PEMEX Curves Sensitivity debt	15,453
U.S [member]
Derivative Financial Instruments [line items]
Sensitivity debt	785,508
Sensitivity DFIs	89,880
Sensitivity net	875,388
PEMEX Curves Sensitivity debt	$ 416,052

XML

Derivative Financial Instruments - Details of Interest rate and currency Derivative Financial Instruments (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)
Switzerland, Francs [member]
Disclosure of financial instruments by type of interest rate [line items]
Debt	$ 3,144
DFIs	(3,144)
1% Debt	(13,624)
EURO [member]
Disclosure of financial instruments by type of interest rate [line items]
Debt	100,081
DFIs	(84,962)
Net	15,119
1% Debt	(167,068)
Pound sterling [member]
Disclosure of financial instruments by type of interest rate [line items]
Debt	7,691
DFIs	(7,073)
Net	618
1% Debt	(12,322)
Japan, Yen [member]
Disclosure of financial instruments by type of interest rate [line items]
Debt	8,542
DFIs	(3,972)
Net	4,570
1% Debt	(14,859)
Mexico, Pesos [member]
Disclosure of financial instruments by type of interest rate [line items]
Debt	43,774
DFIs	2,039
Net	45,813
1% Debt	(133,525)
Mexican Unidad de Inversion [member]
Disclosure of financial instruments by type of interest rate [line items]
1% Debt	(28,573)
Interbank Yield Curves One Percentage [member] | Switzerland, Francs [member]
Disclosure of financial instruments by type of interest rate [line items]
Debt	(13,943)
DFIs	13,943
Interbank Yield Curves One Percentage [member] | EURO [member]
Disclosure of financial instruments by type of interest rate [line items]
Debt	(187,988)
DFIs	165,894
Net	(22,094)
Interbank Yield Curves One Percentage [member] | Pound sterling [member]
Disclosure of financial instruments by type of interest rate [line items]
Debt	(13,822)
DFIs	13,042
Net	(780)
Interbank Yield Curves One Percentage [member] | Japan, Yen [member]
Disclosure of financial instruments by type of interest rate [line items]
Debt	(16,914)
DFIs	11,470
Net	(5,444)
Interbank Yield Curves One Percentage [member] | Mexico, Pesos [member]
Disclosure of financial instruments by type of interest rate [line items]
Debt	(135,974)
DFIs	1,409
Net	(134,565)
Interbank Yield Curves One Percentage [member] | Mexican Unidad de Inversion [member]
Disclosure of financial instruments by type of interest rate [line items]
Debt	(29,485)
DFIs	25,358
Net	(4,127)
Interbank Yield Curves VaR Ninety Percentage [member] | EURO [member]
Disclosure of financial instruments by type of interest rate [line items]
Net	(19,744)
Interbank Yield Curves VaR Ninety Percentage [member] | Pound sterling [member]
Disclosure of financial instruments by type of interest rate [line items]
Net	(666)
Interbank Yield Curves VaR Ninety Percentage [member] | Japan, Yen [member]
Disclosure of financial instruments by type of interest rate [line items]
Net	(4,398)
Interbank Yield Curves VaR Ninety Percentage [member] | Mexico, Pesos [member]
Disclosure of financial instruments by type of interest rate [line items]
Net	(162,336)
Interbank Yield Curves VaR Ninety Percentage [member] | Mexican Unidad de Inversion [member]
Disclosure of financial instruments by type of interest rate [line items]
Net	$ (5,038)

XML

Derivative Financial Instruments - Details of current and potential exposures and aggregated by credit rating (Detail) $ in Thousands	Dec. 31, 2017 USD ($)
Current [member] | A [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	$ 257,424
Current [member] | A - [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	138,850
Current [member] | BBB + [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	310,705
Current [member] | BBB [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	2,183
Less than 1 year [member] | A [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	976,230
Less than 1 year [member] | A - [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	235,594
Less than 1 year [member] | BBB + [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	1,010,356
Less than 1 year [member] | BBB [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	18,626
One to Three Year [member] | A [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	1,298,110
One to Three Year [member] | A - [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	191,681
One to Three Year [member] | BBB + [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	1,540,015
One to Three Year [member] | BBB [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	20,064
3-5 years [member] | A [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	1,314,296
3-5 years [member] | A - [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	228,801
3-5 years [member] | BBB + [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	1,349,311
3-5 years [member] | BBB [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	18,092
5-7 years [member] | A [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	578,548
5-7 years [member] | A - [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	223,751
5-7 years [member] | BBB + [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	1,243,898
7-10 years [member] | A [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	482,959
7-10 years [member] | A - [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	257,465
7-10 years [member] | BBB + [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	1,115,559
More than 10 years [member] | BBB + [member]
Derivative Financial Instruments [line items]
Maximum Credit Exposure by term in Petroleos Mexicanos	$ 78,831

XML

Derivative Financial Instruments - Details of notional amounts of investments in domestic currency and organized by the credit ratings of the issuances (Detail) - Dec. 31, 2017 $ in Thousands, $ in Thousands	USD ($)	MXN ($)
Disclosure of credit risk exposure [line items]
Notional amount	$ 6,700,000	$ 23,500,000
mxAAA [member]
Disclosure of credit risk exposure [line items]
Notional amount		811,548
mxAA [member]
Disclosure of credit risk exposure [line items]
Notional amount		200,876
mxA [member]
Disclosure of credit risk exposure [line items]
Notional amount		$ 271,275

XML

Derivative Financial Instruments - Schedule of current and potential exposure, aggregated by credit rating and derivative financial instruments (Detail) $ in Thousands	Dec. 31, 2017 USD ($)
Current [member] | A [member]
Disclosure of credit risk exposure [line items]
Maximum Credit Exposure by term in Pemex Industrial Transformation	$ 27
Current [member] | A - [member]
Disclosure of credit risk exposure [line items]
Maximum Credit Exposure by term in Pemex Industrial Transformation	541
Current [member] | BBB + [member]
Disclosure of credit risk exposure [line items]
Maximum Credit Exposure by term in Pemex Industrial Transformation	25
Less than 1 year [member] | A [member]
Disclosure of credit risk exposure [line items]
Maximum Credit Exposure by term in Pemex Industrial Transformation	27
Less than 1 year [member] | A - [member]
Disclosure of credit risk exposure [line items]
Maximum Credit Exposure by term in Pemex Industrial Transformation	541
Less than 1 year [member] | BBB + [member]
Disclosure of credit risk exposure [line items]
Maximum Credit Exposure by term in Pemex Industrial Transformation	25
One to Three Year [member] | A - [member]
Disclosure of credit risk exposure [line items]
Maximum Credit Exposure by term in Pemex Industrial Transformation	306
One to Three Year [member] | BBB + [member]
Disclosure of credit risk exposure [line items]
Maximum Credit Exposure by term in Pemex Industrial Transformation	$ 1

XML

Derivative Financial Instruments - Details of quantitative disclosure of debt cash flow's maturities (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
2018 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	$ 125,130,842	$ 148,350,783
2018 [member] | Fixed rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	53,465,817	15,759,027
2018 [member] | Fixed rate (Japanese yen) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt		517,286
2018 [member] | Fixed rate (euros) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	1,043	26,006,880
2018 [member] | Fixed rate (Swiss Francs)) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	4,565,075
2018 [member] | Fixed rate (Australian dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt		2,232,195
2018 [member] | Fixed rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	58,031,935	44,515,388
2018 [member] | Variable rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	58,364,536	38,811,320
2018 [member] | Variable rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	8,734,371	65,024,075
2018 [member] | Variable rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	67,098,907	103,835,395
2019 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	159,403,398	127,349,970
2019 [member] | Fixed rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	59,498,256	86,161,096
2019 [member] | Fixed rate (UDIs) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	18,477,076
2019 [member] | Fixed rate (euros) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	32,042,196
2019 [member] | Fixed rate (Swiss Francs)) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	6,088,686	4,539,022
2019 [member] | Fixed rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	116,106,214	90,700,118
2019 [member] | Variable rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	15,302,101	27,907,661
2019 [member] | Variable rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	27,995,083	8,742,191
2019 [member] | Variable rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	43,297,184	36,649,852
2020 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	209,915,748	162,209,245
2020 [member] | Fixed rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	60,290,621	65,642,616
2020 [member] | Fixed rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	10,033,017
2020 [member] | Fixed rate (UDIs) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	4,764,175	17,319,897
2020 [member] | Fixed rate (euros) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	30,801,894	29,198,138
2020 [member] | Fixed rate (Swiss Francs)) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	12,149,953	6,056,338
2020 [member] | Fixed rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	118,039,660	118,216,989
2020 [member] | Variable rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	62,289,546	15,984,547
2020 [member] | Variable rate (Japanese yen) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	11,244,800
2020 [member] | Variable rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	18,341,742	28,007,709
2020 [member] | Variable rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	91,876,088	43,992,256
2021 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	185,307,669	199,534,891
2021 [member] | Fixed rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	95,232,448	62,440,943
2021 [member] | Fixed rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	20,376,655	10,048,950
2021 [member] | Fixed rate (UDIs) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	3,874,313	4,464,787
2021 [member] | Fixed rate (euros) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	41,508,857	28,061,554
2021 [member] | Fixed rate (Swiss Francs)) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	3,046,567	12,102,748
2021 [member] | Fixed rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	164,038,840	117,118,982
2021 [member] | Variable rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	12,809,666	52,726,647
2021 [member] | Variable rate (Japanese yen) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt		11,341,440
2021 [member] | Variable rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	8,459,163	18,347,822
2021 [member] | Variable rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	21,268,829	82,415,909
2022 thereafter [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	158,761,145	147,813,212
2022 thereafter [member] | Fixed rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	84,076,050	98,858,992
2022 thereafter [member] | Fixed rate (Pounds) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	9,345,839
2022 thereafter [member] | Fixed rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	1,999,098	20,457,671
2022 thereafter [member] | Fixed rate (UDIs) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt		3,630,557
2022 thereafter [member] | Fixed rate (euros) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	23,655,950
2022 thereafter [member] | Fixed rate (Swiss Francs)) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt		3,031,480
2022 thereafter [member] | Fixed rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	119,076,937	125,978,700
2022 thereafter [member] | Variable rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	31,289,725	13,366,336
2022 thereafter [member] | Variable rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	8,394,483	8,468,176
2022 thereafter [member] | Variable rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	39,684,208	21,834,512
Maturity Period Eight [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	1,167,277,644	1,170,097,223
Maturity Period Eight [member] | Fixed rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	808,836,547	826,093,574
Maturity Period Eight [member] | Fixed rate (Japanese yen) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	19,296,607	19,459,306
Maturity Period Eight [member] | Fixed rate (Pounds) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	11,952,816	8,825,434
Maturity Period Eight [member] | Fixed rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	88,349,072	90,393,507
Maturity Period Eight [member] | Fixed rate (UDIs) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	30,081,647	28,288,180
Maturity Period Eight [member] | Fixed rate (euros) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	171,255,634	123,886,644
Maturity Period Eight [member] | Fixed rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	1,129,772,323	1,096,946,645
Maturity Period Eight [member] | Variable rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	18,379,557	45,385,885
Maturity Period Eight [member] | Variable rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	19,125,764	27,764,693
Maturity Period Eight [member] | Variable rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	37,505,321	73,150,578
Net Carrying Amount [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	2,005,796,446	1,955,355,324
Net Carrying Amount [member] | Fixed rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	$ 1,161,399,739	$ 1,154,956,248
Average interest rate (%)	5.7747%	5.6541%
Net Carrying Amount [member] | Fixed rate (Japanese yen) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	$ 19,296,607	$ 19,976,592
Average interest rate (%)	1.3485%	1.3665%
Net Carrying Amount [member] | Fixed rate (Pounds) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	$ 21,298,655	$ 8,825,434
Average interest rate (%)	5.7246%	8.25%
Net Carrying Amount [member] | Fixed rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	$ 120,757,842	$ 120,900,128
Average interest rate (%)	7.4876%	7.4878%
Net Carrying Amount [member] | Fixed rate (UDIs) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	$ 57,197,211	$ 53,703,421
Average interest rate (%)	2.7458%	4.0559%
Net Carrying Amount [member] | Fixed rate (euros) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	$ 299,265,574	$ 207,153,216
Average interest rate (%)	3.6736%	3.9581%
Net Carrying Amount [member] | Fixed rate (Swiss Francs)) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	$ 25,850,281	$ 25,729,588
Average interest rate (%)	1.8387%	1.8385%
Net Carrying Amount [member] | Fixed rate (Australian dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt		$ 2,232,195
Average interest rate (%)		6.125%
Net Carrying Amount [member] | Fixed rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	$ 1,705,065,909	$ 1,593,476,822
Net Carrying Amount [member] | Variable rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	198,435,131	194,182,396
Net Carrying Amount [member] | Variable rate (Japanese yen) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	11,244,800	11,341,440
Net Carrying Amount [member] | Variable rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	91,050,606	156,354,666
Net Carrying Amount [member] | Variable rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	300,730,537	361,878,502
Fair value [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	2,153,383,220	1,988,275,614
Fair value [member] | Fixed rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	1,213,404,769	1,137,936,275
Fair value [member] | Fixed rate (Japanese yen) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	18,040,398	17,336,203
Fair value [member] | Fixed rate (Pounds) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	24,381,394	11,373,345
Fair value [member] | Fixed rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	171,683,692	160,930,040
Fair value [member] | Fixed rate (UDIs) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	56,536,905	50,809,979
Fair value [member] | Fixed rate (euros) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	330,573,998	216,100,006
Fair value [member] | Fixed rate (Swiss Francs)) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	26,957,785	26,469,543
Fair value [member] | Fixed rate (Australian dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt		2,346,390
Fair value [member] | Fixed rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	1,841,578,940	1,623,301,781
Fair value [member] | Variable rate (U.S. dollars) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	206,254,219	195,838,382
Fair value [member] | Variable rate (Japanese yen) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	11,361,079	11,025,531
Fair value [member] | Variable rate (pesos) [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	94,188,981	158,109,920
Fair value [member] | Variable rate [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Outstanding debt	$ 311,804,280	$ 364,973,833

XML

Derivative Financial Instruments - Details of quantitative disclosure of debt cash flow's maturities (Parenthetical) (Detail)	Dec. 31, 2017 $ / $	Dec. 31, 2016
Disclosure of maturity analysis for derivative financial liabilities [line items]
Exchange rates	19.7867
U.S [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Exchange rates	19.7867	20.664
Japan, Yen [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Exchange rates	0.1757	0.17721
Pound sterling [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Exchange rates	26.7724	25.30513
Mexican Unidad de Inversion [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Exchange rates	5.934551	5.562883
EURO [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Exchange rates	23.7549	21.6724
Switzerland, Francs [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Exchange rates	20.2992	20.19744
Australia, Dollars [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Exchange rates	15.4752	14.88428

XML

Derivative Financial Instruments - Summary of Quantitative Disclosure of Cash Flow's Maturities (Detail)	12 Months Ended
	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options	$ 59,360,100
Currency Options Position One [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options	14,046,320
Currency options position two [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options	100,950,853
Currency options position three [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options	12,031,728
Currency Options [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options		$ 14,133,580
2017 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options	59,360,100
2020 [member] | Currency options position two [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options	41,567,998
2022 Thereafter [member] | Currency Options Position One [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options	14,046,320
2022 Thereafter [member] | Currency options position two [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options	59,382,855
2022 Thereafter [member] | Currency options position three [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options	12,031,728
Fair value [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options	(2,006,461)
Fair value [member] | Currency Options Position One [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options	48,715
Fair value [member] | Currency options position two [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options	4,919,444
Fair value [member] | Currency options position three [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options	$ (239,626)
Fair value [member] | Currency Options [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options		(301,131)
Maturity Period Eight [member] | Currency Options [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Currency Options		$ 14,133,580
U.S [member] | Interest Rate Swap 1 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Variable to fixed	33,552,022	39,939,292
U.S [member] | 2017 [member] | Interest Rate Swap 1 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Variable to fixed	4,704,170
Average pay rate	3.16%
Average receive rate	3.19%
U.S [member] | 2018 [member] | Interest Rate Swap 1 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Variable to fixed	4,717,321	4,899,645
Average pay rate	3.18%	2.76%
Average receive rate	3.44%	2.95%
U.S [member] | 2019 [member] | Interest Rate Swap 1 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Variable to fixed	4,730,857	4,912,743
Average pay rate	3.20%	2.66%
Average receive rate	3.69%	2.99%
U.S [member] | 2020 [member] | Interest Rate Swap 1 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Variable to fixed	4,686,396	4,926,477
Average pay rate	3.22%	3.35%
Average receive rate	3.81%	3.03%
U.S [member] | 2021 [member] | Interest Rate Swap 1 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Variable to fixed	4,570,070	4,940,613
Average pay rate	3.26%	3.83%
Average receive rate	3.95%	3.06%
U.S [member] | 2022 Thereafter [member] | Interest Rate Swap 1 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Variable to fixed	10,143,209
Average pay rate	3.48%
Average receive rate	4.48%
U.S [member] | Fair value [member] | Interest Rate Swap 1 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Variable to fixed	388,851	164,716
U.S [member] | 2022 thereafter [member] | Interest Rate Swap 1 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Variable to fixed		4,894,180
Average pay rate		4.04%
Average receive rate		3.11%
U.S [member] | Maturity Period Eight [member] | Interest Rate Swap 1 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Variable to fixed		15,365,634
Average pay rate		4.57%
Average receive rate		3.33%
Receive euros pay us dollars [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	$ 278,440,124	$ 229,016,488
Receive euros pay us dollars [member] | 2018 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	29,898,198	34,775,198
Receive euros pay us dollars [member] | 2019 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	28,719,208
Receive euros pay us dollars [member] | 2020 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	36,902,690	31,223,821
Receive euros pay us dollars [member] | 2021 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	21,302,856	29,992,556
Receive euros pay us dollars [member] | 2022 Thereafter [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	161,617,172
Receive euros pay us dollars [member] | Fair value [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	19,065,727	(16,484,533)
Receive euros pay us dollars [member] | Maturity Period Eight [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps		133,024,913
Receive Japanese yen pay us dollars [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	17,815,114	23,217,534
Receive Japanese yen pay us dollars [member] | 2018 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps		532,711
Receive Japanese yen pay us dollars [member] | 2019 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	13,039,563
Receive Japanese yen pay us dollars [member] | 2021 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps		17,697,534
Receive Japanese yen pay us dollars [member] | 2022 Thereafter [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	4,775,551
Receive Japanese yen pay us dollars [member] | Fair value [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	(1,670,533)	(6,132,633)
Receive Japanese yen pay us dollars [member] | Maturity Period Eight [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps		4,987,289
Receive pounds sterling pay us dollars [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	22,017,215	10,767,349
Receive pounds sterling pay us dollars [member] | 2021 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	10,310,216
Receive pounds sterling pay us dollars [member] | 2022 Thereafter [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	11,706,999
Receive pounds sterling pay us dollars [member] | Fair value [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	1,151,096	(211,207)
Receive pounds sterling pay us dollars [member] | Maturity Period Eight [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps		10,767,349
Receive udi pay pesos [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	54,638,028	44,593,759
Receive udi pay pesos [member] | 2018 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	23,740,341
Receive udi pay pesos [member] | 2019 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	7,292,520
Receive udi pay pesos [member] | 2020 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	3,000,000	23,740,341
Receive udi pay pesos [member] | 2021 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps		3,540,220
Receive udi pay pesos [member] | 2022 Thereafter [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	20,605,166
Receive udi pay pesos [member] | Fair value [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	(4,720,592)	(2,132,236)
Receive udi pay pesos [member] | 2022 thereafter [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps		3,000,000
Receive udi pay pesos [member] | Maturity Period Eight [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps		14,313,198
Receive swiss francs pay us dollars [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	25,579,588	26,713,732
Receive swiss francs pay us dollars [member] | 2017 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	4,535,474
Receive swiss francs pay us dollars [member] | 2018 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	6,501,082
Receive swiss francs pay us dollars [member] | 2019 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	11,548,658	4,736,567
Receive swiss francs pay us dollars [member] | 2020 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	2,994,374	6,789,326
Receive swiss francs pay us dollars [member] | 2021 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps		12,060,700
Receive swiss francs pay us dollars [member] | Fair value [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps	$ 400,316	(789,449)
Receive swiss francs pay us dollars [member] | 2022 thereafter [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps		3,127,139
Receive australian dollars pay dollars [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps		2,459,429
Receive australian dollars pay dollars [member] | 2018 [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps		2,459,429
Receive australian dollars pay dollars [member] | Fair value [member] | Cross - currency swaps [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Received cross currency swaps		$ (126,796)

XML

Derivative Financial Instruments - Summary of Quantitative Disclosure of Cash Flow's Maturities (Parenthetical) (Detail)	Dec. 31, 2017 $ / $	Dec. 31, 2016
Disclosure of maturity analysis for derivative financial liabilities [line items]
Exchange rates	19.7867
U.S [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Exchange rates	19.7867	20.664
EURO [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Exchange rates	23.7549	21.6724

XML

Derivative Financial Instruments - Summary of Fair Values and Notional Amounts of DFIs that were designated as non-hedges (Detail) $ in Thousands	Dec. 31, 2017 USD ($) MMB	Dec. 31, 2017 MXN ($) MMB	Dec. 31, 2016 MXN ($) MMB
Disclosure of detailed information about hedging instruments [line items]
Notional amount	$ 6,700,000	$ 23,500,000,000
Fair Value		17,337,760,000	$ (26,010,486,000)
Interest Rate Swaps Position One [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		16,695,028,000	20,018,250,000
Fair Value		79,448,000	(90,451,000)
Interest Rate Swaps Position Two [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		15,433,626,000	18,132,660,000
Fair Value		332,273,000	312,210,000
Cross Currency Swaps Position One [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		23,740,341,000	23,740,341,000
Fair Value		(4,504,151,000)	(4,815,373,000)
Cross Currency Swaps Position Two [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		30,897,687,000	20,853,418,000
Fair Value		(216,441,000)	2,683,138,000
Cross Currency Swaps Position Three [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		4,775,551,000	5,520,000,000
Fair Value		134,461,000	(116,507,000)
Cross Currency Swaps Position Four [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		13,039,563,000	17,697,534,000
Fair Value		(1,804,993,000)	(6,016,126,000)
Cross Currency Swaps Position Five [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		278,440,124,000	229,016,488,000
Fair Value		19,065,727,000	(16,484,533,000)
Cross currency swaps position nine [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		11,706,999,000
Fair Value		590,113,000
Cross Currency Swaps Position Six [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		10,310,216,000	10,767,349,000
Fair Value		560,982,000	(211,207,000)
Cross Currency Swaps Position Seven [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		25,579,588,000	26,713,732,000
Fair Value		400,316,000	(789,449,000)
Cross Currency Swaps Position Eight [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount			2,459,429,000
Fair Value			(126,796,000)
Currency Options Position One [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		14,046,320,000	14,133,580,000
Fair Value		48,715,000	(301,131,000)
Currency options position three [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		100,950,853,000
Fair Value		4,919,444,000
Currency options position two [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		12,031,728,000
Fair Value		(239,626,000)
Currency forward Position one [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		59,360,100,000
Fair Value		(2,006,461,000)
Natural Gas Swaps Position One [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		(51,724,000)	(160,214,000)
Fair Value		6,934,000	(25,145,000)
Natural Gas Swaps Position Two [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		50,846,000	157,545,000
Fair Value		(6,114,000)	27,869,000
Natural Gas Options Position One [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		18,625,000	73,653,000
Fair Value		398,000	11,548,000
Natural Gas Options Position Two [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		(18,625,000)	(73,653,000)
Fair Value		(397,000)	(11,488,000)
Interest Rate Swaps Position Three [member]
Disclosure of detailed information about hedging instruments [line items]
Notional amount		1,423,368,000	1,788,382,000
Fair Value		$ (22,870,000)	$ (57,043,000)
Crude oil options [member]
Disclosure of detailed information about hedging instruments [line items]
Volume | MMB	153.56	153.56
Fair Value		$ (5,010,187)
Futures [member] | Exchange trade [member]
Disclosure of detailed information about hedging instruments [line items]
Volume | MMB	2.1	2.1
Fair Value		$ (141,693,000)
Petroleum product swaps [member] | Exchange trade [member]
Disclosure of detailed information about hedging instruments [line items]
Volume | MMB	1.3	1.3	4.1
Fair Value		$ (99,680,000)	$ (688,016,000)

XML

Derivative Financial Instruments - Summary of Location on the Consolidated Statement of Financial Position and the Fair Value of DFIs (Detail) $ in Thousands, $ in Thousands	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)
Disclosure of detailed information about financial instruments [line items]
Fair value	$ (896,864)	$ (17,745,979)	$ (30,867,956)
Derivatives liabilities		12,367,475	(26,010,486)
Derivatives not designated as hedges [member]
Disclosure of detailed information about financial instruments [line items]
Fair value		30,113,454	4,857,470
Derivatives liabilities		(17,745,979)	(30,867,956)
Derivatives not designated as hedges [member] | Crude oil options [member]
Disclosure of detailed information about financial instruments [line items]
Fair value		397,630
Derivatives liabilities		(5,407,817)
Derivatives not designated as hedges [member] | Currency Options [member]
Disclosure of detailed information about financial instruments [line items]
Fair value		4,968,159
Derivatives liabilities			(301,131)
Derivatives not designated as hedges [member] | Natural gas options [member]
Disclosure of detailed information about financial instruments [line items]
Fair value		398	11,548
Derivatives liabilities		(397)	(11,488)
Derivatives not designated as hedges [member] | Cross - currency swaps [member]
Disclosure of detailed information about financial instruments [line items]
Fair value		24,126,452	4,503,550
Derivatives liabilities		(10,301,983)	(30,380,405)
Derivatives not designated as hedges [member] | Natural gas swaps [member]
Disclosure of detailed information about financial instruments [line items]
Fair value		7,003	30,162
Derivatives liabilities		(6,182)	(27,438)
Derivatives not designated as hedges [member] | Interest rate swaps [member]
Disclosure of detailed information about financial instruments [line items]
Fair value		411,721	312,210
Derivatives liabilities		(22,870)	$ (147,494)
Derivatives not designated as hedges [member] | Others [member]
Disclosure of detailed information about financial instruments [line items]
Fair value		202,091
Derivatives liabilities		(269)
Derivatives not designated as hedges [member] | Forwards [member]
Disclosure of detailed information about financial instruments [line items]
Derivatives liabilities		$ (2,006,461)

XML

Derivative Financial Instruments - Summary of Net Gain (Loss) Recognized in Income on Derivative Financial Instruments (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of detailed information about financial instruments [line items]
Net gain loss on derivatives	$ 25,338,324	$ (14,000,987)	$ (21,449,877)
Derivatives not designated as hedges [member] | Forwards [member]
Disclosure of detailed information about financial instruments [line items]
Net gain loss on derivatives	(1,976,241)
Derivatives not designated as hedges [member] | Futures [member]
Disclosure of detailed information about financial instruments [line items]
Net gain loss on derivatives	(779,950)	(1,925,969)	1,387,177
Derivatives not designated as hedges [member] | Crude oil options [member]
Disclosure of detailed information about financial instruments [line items]
Net gain loss on derivatives	(3,771,604)
Derivatives not designated as hedges [member] | Currency Options [member]
Disclosure of detailed information about financial instruments [line items]
Net gain loss on derivatives	5,255,931	(298,789)
Derivatives not designated as hedges [member] | Natural gas options [member]
Disclosure of detailed information about financial instruments [line items]
Net gain loss on derivatives	673	(671)	4,786
Derivatives not designated as hedges [member] | Cross - currency swaps [member]
Disclosure of detailed information about financial instruments [line items]
Net gain loss on derivatives	27,747,290	(11,633,605)	(21,358,898)
Derivatives not designated as hedges [member] | Natural gas swaps [member]
Disclosure of detailed information about financial instruments [line items]
Net gain loss on derivatives	1,780	831	4,355
Derivatives not designated as hedges [member] | Propane swaps [member]
Disclosure of detailed information about financial instruments [line items]
Net gain loss on derivatives		(3,805)	(1,136,188)
Derivatives not designated as hedges [member] | Interest rate swaps [member]
Disclosure of detailed information about financial instruments [line items]
Net gain loss on derivatives	(34,306)	$ (138,979)	$ (351,109)
Derivatives not designated as hedges [member] | Others [member]
Disclosure of detailed information about financial instruments [line items]
Net gain loss on derivatives	$ (1,105,249)

XML

Derivative Financial Instruments - Schedule of Financial Assets and Liabilities Measured at Fair Value and Indicate the Fair Value Hierarchy of the Inputs Utilized to Determine the Fair Values (Detail) - MXN ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Derivative Financial Assets [member]
Disclosure of fair value measurement of assets and liabilities [Line Items]
Derivative financial instruments	$ 30,113,454	$ 4,857,470
Available-for-sale financial assets	1,056,918	8,880,219
Derivative liabilities [member]
Disclosure of fair value measurement of assets and liabilities [Line Items]
Derivative financial instruments	(17,745,979)	(30,867,956)
Level 1 [member] | Derivative Financial Assets [member]
Disclosure of fair value measurement of assets and liabilities [Line Items]
Available-for-sale financial assets		6,463,096
Level 2 [member] | Derivative Financial Assets [member]
Disclosure of fair value measurement of assets and liabilities [Line Items]
Derivative financial instruments	30,113,454	4,857,470
Available-for-sale financial assets	1,056,918	2,417,123
Level 2 [member] | Derivative liabilities [member]
Disclosure of fair value measurement of assets and liabilities [Line Items]
Derivative financial instruments	$ (17,745,979)	$ (30,867,956)

XML

Financial Instruments - Schedule of Carrying Value and the Estimated Fair Value of the Remaining Financial Assets and Liabilities (Detail) $ in Thousands, $ in Thousands	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)	Dec. 31, 2014 MXN ($)
Disclosure Of Fair Value Financial Assets And Liabilities [Line Items]
Cash and cash equivalents	$ 4,945,330	$ 97,851,754	$ 8,264,769	$ 163,532,513	$ 109,368,880	$ 117,988,528
Accounts receivable, net	8,624,239	170,645,234		133,220,527
Long-term notes receivable	7,504,683	148,492,909		148,607,602
Suppliers	7,073,205	139,955,378		151,649,540
Accounts and accrued expenses payable	1,173,081	23,211,401		18,666,607
Short-term debt and current portion of long-term debt	7,945,209	157,209,467		176,166,188
Long-term debt	$ 95,046,956	1,880,665,604		1,807,004,542	$ 1,300,873,167
Fair value [member]
Disclosure Of Fair Value Financial Assets And Liabilities [Line Items]
Cash and cash equivalents		97,851,754		163,532,513
Accounts receivable, net		170,645,234		133,220,527
Long-term notes receivable		148,492,909		148,607,602
Suppliers		139,955,378		151,649,540
Accounts and accrued expenses payable		23,211,401		18,666,607
Short-term debt and current portion of long-term debt		157,209,467		176,166,188
Long-term debt		$ 1,996,173,753		$ 1,812,109,426

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Employee Benefits - Summary of Amounts Associated With PEMEX's Labor Obligations (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure of defined benefit plans [line items]
Liability for defined benefits at retirement and post-employment at the end of the year				$ (103,860,955)
Total liability for defined benefits recognized in the consolidated statement of financial position at the end of the year	$ 2,530,255	$ 50,065,396	$ 47,293,069	$ (116,022,232)
PEMEX [member]
Disclosure of defined benefit plans [line items]
Liability for defined benefits at retirement and post-employment at the end of the year		1,241,072,307	1,202,624,665
Liability for other long-term benefits		17,363,815	17,784,771
Total liability for defined benefits recognized in the consolidated statement of financial position at the end of the year		$ 1,258,436,122	$ 1,220,409,436

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Employee Benefits - Summary of Information Regarding PEMEX's Retirement and Post-Employment Benefits (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Actuarial (gains) losses in other comprehensive results due to:
Plan assets at the beginning of year	$ 9,489,666
Company contributions to the fund	63,500,000
Pension plan assets at the end of year	8,485,692	$ 9,489,666
Plan assets [member]
Changes in the liability for defined benefits
Defined benefit obligations at the beginning of the year	1,212,114,331	1,263,708,928
Recognition of the modifications in pensions plan	(6,609,657)	(571,713)
Current Service cost	19,762,661	23,107,851
Past service costs		(33,244)
Actuarial (gains) losses in other comprehensive results due to:
Remeasurements	(1,471)
Defined benefit liabilities at end of year	1,249,557,999	1,212,114,331
Plan assets at the beginning of year	9,489,666	5,228,909
Return on plan assets	902,550	742,477
Payments by the pension fund	(54,312,270)	(51,889,821)
Company contributions to the fund	51,952,559	55,693,256
Actuarial (gains) losses in plan assets	453,187	(285,155)
Pension plan assets at the end of year	8,485,692	9,489,666
Retirement And Post Employment Benefits [member]
Changes in the liability for defined benefits
Defined benefit obligations at the beginning of the year	1,202,624,665	1,258,480,019
Recognition of the modifications in pensions plan	8,327	(571,713)
Current Service cost	13,079,341	23,111,918
Net interest	95,402,917	90,527,624
Past service costs		(33,244)
Defined benefits paid by the fund	(5,105,669)	(4,892,767)
Actuarial (gains) losses in other comprehensive results due to:
Change in financial assumptions	47,182,448	(149,533,263)
Change in demographic assumptions	(70,012,604)	4,842,109
For experience during the year	10,272,231	36,103,857
In plan assets during the year	(453,206)	285,123
Remeasurements	26,417	(1,742)
Contributions paid to the fund	(51,952,560)	(55,693,256)
Defined benefit liabilities at end of year	$ 1,241,072,307	$ 1,202,624,665

XML

Employee Benefits - Additional Information (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Disclosure of defined benefit plans [line items]
Net actuarial gains recognized in other comprehensive income	$ 12,038,710	$ 106,387,640
Percentage increase in discount and expected return on plan assets	12.46%
Expected contribution to the fund	$ 63,500,000
Expected payments	$ 62,337,560
Percentage of decrease in assumed variation rate	(15.72%)
Medical services of increase or decrease of one percentage point [member]
Disclosure of defined benefit plans [line items]
Percentage increase in discount and expected return on plan assets	21.93%
Percentage of decrease in assumed variation rate	(16.80%)
Actuarial assumption of discount rates [member]
Disclosure of defined benefit plans [line items]
Percentage increase in discount and expected return on plan assets	7.89%	8.17%

XML

Employee Benefits - Summary of Amounts and Types of Plan Assets (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of fair value of plan assets [line items]
Cash and cash equivalents	$ 135,757	$ 5,906,660
Equity instruments	1,034,178	2,694,291
Debt instruments	7,315,757	888,715
Total plan assets	8,485,692	9,489,666
Change in the liability for defined benefits
Payments by the fund	(62,337,560)
Plan assets [member]
Disclosure of fair value of plan assets [line items]
Cash and cash equivalents	135,757	5,906,660
Equity instruments	1,034,178	2,694,291
Debt instruments	7,315,757	888,715
Total plan assets	8,485,692	9,489,666	$ 5,228,909
Change in the liability for defined benefits
Defined benefit obligations at the beginning of the year	1,212,114,331	1,263,708,928
Service costs	19,762,661	23,107,851
Financing costs	96,331,015	91,270,383
Past service costs		(33,244)
Payments by the fund	(59,417,940)	(56,778,359)
Amount of (gains) and losses recognized through other comprehensive income:	(12,594,541)	(108,589,515)
Modifications to the pension plan	(6,609,657)	(571,713)
Remeasurements	(1,471)
Reductions	(26,399)
Defined benefit liabilities at end of year	$ 1,249,557,999	$ 1,212,114,331

XML

Employee Benefits - Summary of Additional Fair value Disclosure About Plan Assets and Indicate Their Rank (Detail) - MXN ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Disclosure of fair value of plan assets [line items]
Cash and cash equivalents	$ 135,757	$ 5,906,660
Equity instruments	1,034,178	2,694,291
Debt instruments	7,315,757	888,715
Total	8,485,692	9,489,666
Level 1 [member]
Disclosure of fair value of plan assets [line items]
Cash and cash equivalents	135,757	5,906,660
Equity instruments	1,034,178	2,694,291
Debt instruments	7,315,757	888,715
Total	$ 8,485,692	$ 9,489,666

XML

Employee Benefits - DisclosureOfSensitivityAnalysisForActuarialAssumptionsExplanatory (Detail)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Discount and return on plan assets rate	12.46%
Average length of obligation (years)	18 years 4 months 24 days	17 years 8 months 1 day
Actuarial assumption of expected rates of salary increases [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Discount and return on plan assets rate	4.77%	4.77%
Actuarial assumption of expected rates of pension increases [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Discount and return on plan assets rate	3.75%	3.75%
Medical services [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Discount and return on plan assets rate	7.65%	7.65%
Actuarial assumption of expected rates of inflation [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Discount and return on plan assets rate	3.75%	3.75%
Actuarial assumption of discount rates [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Discount and return on plan assets rate	7.89%	8.17%

XML

Employee Benefits - Summary of Amounts Recognized for Long-term Obligations (Detail) - Other Long-term Benefits [member] - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Change in the liability for defined benefits
Defined benefit obligations at the beginning of the year	$ 17,784,771	$ 20,905,422
Charge to income for the year	3,277,847	3,420,158
Actuarial (gains) losses recognized in income due to:
Change in financial assumptions	878,516	(3,028,211)
Change in demographic assumptions	(1,015,274)	(119,982)
For experience during the year	(3,558,599)	(3,390,396)
Benefits paid	(3,446)	(2,220)
Defined benefit liabilities at end of year	$ 17,363,815	$ 17,784,771

XML

Employee Benefits - Summary of Principal Actuarial Assumptions Used in Determining the Defined Benefit Obligation (Detail)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Discount and return on plan assets rate	12.46%
Average length of obligation (years)	18 years 4 months 24 days	17 years 8 months 1 day
Actuarial assumption of expected rates of salary increases [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Discount and return on plan assets rate	4.77%	4.77%
Actuarial assumption of expected rates of inflation [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Discount and return on plan assets rate	3.75%	3.75%
Actuarial assumption of discount rates [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Discount and return on plan assets rate	7.89%	8.17%
Other Long-term Benefits [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Average length of obligation (years)	18 years 4 months 24 days	17 years 8 months 2 days
Other Long-term Benefits [member] | Actuarial assumption of expected rates of salary increases [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Discount and return on plan assets rate	4.77%	4.77%
Other Long-term Benefits [member] | Actuarial assumption of expected rates of inflation [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Discount and return on plan assets rate	3.75%	3.75%
Other Long-term Benefits [member] | Actuarial assumption of discount rates [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Discount and return on plan assets rate	7.89%	8.17%

XML

Provisions for Sundry Creditors - Summary of Provisions for Sundry Creditors and Others (Detail) $ in Thousands, $ in Thousands	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure of other provisions [abstract]
Provision for plugging of wells (Note 12)		$ 68,797,600	$ 64,967,710	$ 56,894,695
Provision for trails in process (Note 25)		7,812,689	15,119,692	12,775,263
Provision for environmental costs		11,067,134	8,230,476	$ 3,521,838
Provisions	$ 4,431,129	$ 87,677,423	$ 88,317,878

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Provisions for Sundry Creditors - Summary of Allowance Account for Plugging of Wells, Trials in Progress and Environmental Costs (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Disclosure of other provisions [abstract]
Balance at the beginning of the year	$ 64,967,710	$ 56,894,695
Decrease capitalized in fixed assets	(3,791,482)	(3,878,503)
Unwinding of discount against income	7,774,000	11,968,966
Amount used	(152,628)	(17,448)
Balance at the end of the year	68,797,600	64,967,710
Balance at the beginning of the year	15,119,692	12,775,263
Additions against income	2,835,357	3,049,202
Provision cancellation	(1,973,153)	(632,806)
Amount used	(8,169,207)	(71,967)
Balance at the end of the year	7,812,689	15,119,692
Balance at the beginning of the year	8,230,476	3,521,838
Additions against income	3,203,982	6,118,454
Provision cancellation	(312,937)	(1,347,285)
Amount used	(54,387)	(62,531)
Balance at the end of the year	$ 11,067,134	$ 8,230,476

XML

Provisions for Sundry Creditors - Additional Information (Detail)	Dec. 31, 2017
Bottom of range [member]
Disclosure of other provisions [line items]
Present value is determined based on discount rates	4.00%
Top of range [member]
Disclosure of other provisions [line items]
Present value is determined based on discount rates	10.50%

XML

Disclosures of Cash Flow - Summary of Non-cash Transactions and are Presented for Disclosure Purposes (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating activities
Employee benefits equity effect	$ 12,038,710	$ 106,277,761	$ 78,556,569
Net (benefits) cost of the year for employee benefits	108,073,074	109,738,416	(62,549,142)
Investing activities
Available-for-sale financial assets	5,564,130	207,817	(3,206,316)
Financing activities
Financed Public Works Contracts		146,217,292	2,001,093
Currency translation effect	(7,597,283)	21,386,902	13,262,101
Accrued interest	$ 8,734,131	$ 9,326,945	$ 4,816,784

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Income Taxes and Federal Duties - Additional Information (Detail) $ in Thousands									12 Months Ended
	Jan. 01, 2019	Dec. 31, 2017 MXN ($) $ / km²	Nov. 30, 2017 MXN ($)	Aug. 18, 2017 MXN ($)	Jan. 01, 2017	Nov. 16, 2016 MXN ($)	Apr. 18, 2016 MXN ($)	Jan. 01, 2016	Dec. 31, 2017 MXN ($) $ / km² $ / l $ / T	Dec. 31, 2016 MXN ($)
Disclosure of Income Tax [Line items]
Decrease in applicable tax rate		65.00%
Profit sharing duty | $									$ 338,044,209	$ 277,161,804
Tax benefit from exploration and extraction activities | $			$ 8,854,391	$ 7,769,915			$ 40,213,913
Compensation authorized for exploration and extraction activities | $									2,186,963
Fiscal support (Profit-sharing duty) | $						$ 28,439,379				28,439,379
Payments made for extraction duty | $									58,523,125
Payments made for exploration duty | $									$ 980,843
Payments made for exploration and extraction duty | $		$ 3,986,112
Applicable tax rate									30.00%
Tax regime applicable to assignments [member]
Disclosure of Income Tax [Line items]
Tax payable for non-producing areas | $ / km²		1,214.21							1,214.21
Tax payable for non-producing areas increased amount | $ / km²		2,903.54							2,903.54
Tax payable for exploration phase | $ / km²		1,583.74							1,583.74
Tax payable for extraction phase | $ / km²		6,334.98							6,334.98
Tax regime applicable to contracts [member]
Disclosure of Income Tax [Line items]
Tax payable for non-producing areas | $ / km²		1,175.42							1,175.42
Tax payable for non-producing areas increased amount | $ / km²		2,810.78							2,810.78
Tax payable for exploration phase | $ / km²		1,583.74							1,583.74
Tax payable for extraction phase | $ / km²		6,334.98							6,334.98
Exploration [member]
Disclosure of Income Tax [Line items]
Applicable tax rate of profit-sharing duty					67.50%			68.75%
Decrease in applicable tax rate	65.00%
Profit sharing duty | $									$ 372,902,629	304,299,019
Profit sharing duty monthly installment | $									377,192,377	301,050,325
Profit sharing duty payable | $									$ 4,289,748	$ 3,248,694
Sale of Automotive Fuels [member] | Magna Gasoline [member]
Disclosure of Income Tax [Line items]
Special tax on production and services (IEPS Tax)									4.30
Sale of Automotive Fuels [member] | Premium Gasoline [member]
Disclosure of Income Tax [Line items]
Special tax on production and services (IEPS Tax)									3.64
Sale of Automotive Fuels [member] | Diesel [member]
Disclosure of Income Tax [Line items]
Special tax on production and services (IEPS Tax)									4.73
States and Municipalities [member] | Magna Gasoline [member]
Disclosure of Income Tax [Line items]
Special tax on production and services (IEPS Tax)									38.00
States and Municipalities [member] | Premium Gasoline [member]
Disclosure of Income Tax [Line items]
Special tax on production and services (IEPS Tax)									46.37
States and Municipalities [member] | Diesel [member]
Disclosure of Income Tax [Line items]
Special tax on production and services (IEPS Tax)									31.54
Fossil Fuels [member] | Diesel [member]
Disclosure of Income Tax [Line items]
Special tax on production and services (IEPS Tax)									13.84
Fossil Fuels [member] | Propane [member]
Disclosure of Income Tax [Line items]
Special tax on production and services (IEPS Tax)									6.50
Fossil Fuels [member] | Butane [member]
Disclosure of Income Tax [Line items]
Special tax on production and services (IEPS Tax)									8.42
Fossil Fuels [member] | Jet and Other Fuel [member]
Disclosure of Income Tax [Line items]
Special tax on production and services (IEPS Tax)									11.41
Fossil Fuels [member] | Turbosine and Other Kerosene [member]
Disclosure of Income Tax [Line items]
Special tax on production and services (IEPS Tax)									13.64
Fossil Fuels [member] | Fuel Oil [member]
Disclosure of Income Tax [Line items]
Special tax on production and services (IEPS Tax)									14.78
Fossil Fuels [member] | Petroleum Coke [member]
Disclosure of Income Tax [Line items]
Special tax on production and services (IEPS Tax) | $ / T									17.15

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Income Taxes and Federal Duties - Summary of Total DUC and Others (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Disclosure Of Duties And Others [Line Items]
DUC	$ (338,044,209)	$ (277,161,804)
DUC from prior years	(2,095,429)
Other	(260,775)	(514,356)
DUC [member]
Disclosure Of Duties And Others [Line Items]
DUC	372,902,629	304,299,019
DUC from prior years	2,095,429
Other	260,775	514,356
Deferred DUC benefit	(37,214,624)	(27,651,571)
Total DUC and other	$ 338,044,209	$ 277,161,804

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Income Taxes And Federal Duties - Summary of Principal Factors Generating the Deferred DUC (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2015 MXN ($)
Deferred DUC asset
Provisions		$ 88,317,878	$ 4,431,129	$ 87,677,423
Total deferred DUC asset		(100,324,689)	(7,388,422)	(146,192,485)
Deferred Profit-sharing duty liability
Wells, pipelines, properties, plant and equipment		(1,667,742,248)	(72,599,743)	(1,436,509,326)	$ (1,344,483,631)
Deferred DUC liability		4,134,536	$ 214,988	4,253,928
DUC [member]
Deferred DUC asset
Provisions		570,544,863		541,360,940
Total deferred DUC asset		570,544,863		541,360,940
Deferred Profit-sharing duty liability
Wells, pipelines, properties, plant and equipment		(473,406,721)		(455,697,786)
Deferred DUC liability		(473,406,721)		(455,697,786)
Deferred asset net		97,138,142		85,663,154
Valuation reserve	$ (20,796,959)	(69,486,571)
Net, deferred DUC asset		$ 27,651,571		$ 64,866,195

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Income Taxes And Federal Duties - Summary of Expected Benefit for DUC (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Disclosure Of Expected Benefit For DUC [Abstract]
Expected expense	$ 127,436,912	$ 159,897,683
Increase (decrease) resulting from:
Non-cumulative profit	(514,780,219)	(423,761,673)
Non-deductible expenses	387,343,306	263,863,990
Production value	518,433,469	441,655,000
Deductible duties	(39,503,110)	(29,918,201)
Deferred DUC reserve	(48,689,612)	69,486,571
Deductions cap	(94,552,741)	(204,575,922)
DUC from prior years	2,095,429
Other	260,775	514,356
DUC-Profit-sharing duty expense	$ 338,044,209	$ 277,161,804

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Income Taxes And Federal Duties - Summary of Income Tax Expense (Benefit) (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure Of Income Taxes [Line Items]
Income tax expense	$ (255,938)	$ (5,064,168)	$ (12,640,369)	$ (45,587,267)
PEMEX [member]
Disclosure Of Income Taxes [Line Items]
Current income tax		3,546,912	6,201,842	7,426,892
Deferred income tax		(9,334,064)	(18,842,211)	(53,014,159)
Income tax expense		(5,787,152)	$ (12,640,369)	$ (45,587,267)
Income tax REFIPRE (Preferent Fiscal Regime)		$ 722,984

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Income Taxes and Federal Duties - Summary of Principal Factors Generating Deferred Income Tax (Detail) $ in Thousands, $ in Thousands	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Deferred income tax asset:
Total deferred income tax asset	$ (7,388,422)	$ (146,192,485)	$ (100,324,689)
PEMEX [member]
Deferred income tax asset:
Provisions		8,299,818	5,906,581	$ 25,414,822
Employee benefits provision		130,075,323	125,973,332	247,834,882
Advance payments from clients		2,774,306	1,046,010	1,015,357
Accrued liabilities		371,987	2,269,561	1,514
Non-recoverable accounts receivable		739,748	778,179	104,346
Derivative financial instruments		79,255	223,518	22,506
Wells, pipelines, properties and equipment		405,439,818	458,273,897	446,970,333
Tax loss carryforwards		34,110,960	43,327,737	14,894,231
Total deferred income tax asset		581,891,215	637,798,815	736,257,991
Valuation reserve		(500,564,925)	(565,125,697)	(681,357,607)
Deferred asset net		81,326,290	72,673,118	54,900,384
Deferred income tax liability:
Wells, pipelines, properties plant and equipment		(3,443,618)	(3,632,294)	(1,909,529)
Other		(810,310)	(502,242)	(274,305)
Total deferred income tax liability		(4,253,928)	(4,134,536)	(2,183,834)
Net long-term deferred income tax liability		77,072,362	68,538,582	$ 52,716,550
PEMEX [member] | Recognized in profit and loss [member]
Deferred income tax asset:
Provisions		2,393,237	(19,508,241)
Employee benefits provision		4,902,275	(119,837,137)
Advance payments from clients		1,728,296	30,653
Accrued liabilities		(1,897,574)	2,268,047
Non-recoverable accounts receivable		(38,431)	673,833
Derivative financial instruments		(144,263)	201,012
Wells, pipelines, properties and equipment		(52,834,079)	11,303,564
Tax loss carryforwards		(9,216,777)	28,433,506
Total deferred income tax asset		(55,107,316)	(96,434,763)
Valuation reserve		64,560,772	116,231,910
Deferred asset net		9,453,456	19,797,147
Deferred income tax liability:
Wells, pipelines, properties plant and equipment		188,676	(726,999)
Other		(308,068)	(227,937)
Total deferred income tax liability		(119,392)	(954,936)
Net long-term deferred income tax liability		9,334,064	18,842,211
PEMEX [member] | Recognized in OCI and equity [member]
Deferred income tax asset:
Employee benefits provision		(800,284)	(2,024,413)
Total deferred income tax asset		(800,284)	(2,024,413)
Deferred asset net		(800,284)	(2,024,413)
Deferred income tax liability:
Wells, pipelines, properties plant and equipment			(995,766)
Total deferred income tax liability			(995,766)
Net long-term deferred income tax liability		$ (800,284)	$ (3,020,179)

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Income Taxes and Federal Duties - Summary of Principal Factors Generating Deferred Income Tax (Parenthetical) (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2017 MXN ($)
Disclosure of income taxes [abstract]
Tax loss carryforwards expire	2027
Business combination in equity	$ (995,766)

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Income Taxes and Federal Duties - Summary of Expense (Benefit) Attributable to Profit (Loss) from Continuing Operations before Income Taxes (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure Of Income Taxes [Line Items]
Income tax expense	$ (255,938)	$ (5,064,168)	$ (12,640,369)	$ (45,587,267)
Deferred tax effect of gains and losses		(800,284)
PEMEX [member]
Disclosure Of Income Taxes [Line Items]
Expected income tax expense		(20,055,588)	(14,901,324)	(3,089,241)
Tax effect of inflation-net		14,302,118	8,098,213	(1,618,327)
Difference between accounting and tax depreciation		(3,713,920)	(1,765,183)	(107,231)
Non-deductible expenses		1,954,659	1,558,120	(1,921,515)
Others-net		(1,725,579)	(5,630,195)	(38,850,953)
Income tax expense		$ (5,787,152)	$ (12,640,369)	$ (45,587,267)

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Income Taxes and Federal Duties - Summary of Expense (Benefit) Attributable to Profit (Loss) from Continuing Operations before Income Taxes (Parenthetical) (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure Of Income Taxes [Line Items]
Deferred tax effect of gains and losses	$ (800,284)
Accumulated effect on deferred tax of gains and losses from actuarial gains and losses	17,688,032	$ 16,887,748
PMI CIM [member]
Disclosure Of Income Taxes [Line Items]
Deferred tax effect of gains and losses	$ (2,024,413)		$ (124,285)

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Equity (Deficit), Net - Additional Information (Detail) - MXN ($) $ in Thousands					1 Months Ended	12 Months Ended
	Apr. 21, 2016	Dec. 24, 2015	Jul. 01, 2015	Jan. 19, 2015	Aug. 15, 2016	Dec. 31, 2017	Dec. 31, 2016	Aug. 03, 2016	Jun. 29, 2016
Disclosure of equity [Line Items]
Acquisition percentage of shares			100.00%
Gain (loss) on non-controlling interest						$ 965,107	$ 976,705
Contributions A [member]
Disclosure of equity [Line Items]
Equity contribution	$ 26,500,000			$ 10,000,000
Issue of a non-negotiable promissory note		$ 50,000,000
Maturity date on promissory note		Dec. 31, 2050
Promissory note issued								$ 184,230,586	$ 184,230,586
Increase amount in equity		$ 135,439,612
Increase in the discount value of the promissory notes					$ 1,209,026

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Equity (Deficit ), Net - Summary of Permanent Equity (Detail) - Contributions A [member] - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Disclosure of equity [Line Items]
Certificates of Contribution, Beginning Balance	$ 356,544,447	$ 194,604,835
Increase in Certificates of Contribution during period	0	161,939,612
Certificates of Contribution, Ending Balance	$ 356,544,447	$ 356,544,447

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Other Revenues and Expenses - Net - Summary of Other Revenues and Expenses, net (Detail) - MXN ($) $ in Thousands		12 Months Ended
	Nov. 16, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenues:
Claims recovery		$ 16,386,250	$ 3,695,217	$ 1,975,281
Fiscal support (Profit-sharing duty)	$ 28,439,379		28,439,379
Other income for services		4,720,546	4,266,854	3,953,888
Price of sale share		3,139,103	22,684,736
Other		4,277,207	14,228,801	6,992,954
Revenues from reinsurance premiums		1,986,568	3,694,026	1,497,779
Franchise fees		917,934	1,059,333	1,148,528
Bidding terms, sanctions, penalties and other		825,956	3,223,437	1,262,458
Gain on sale of fixed assets			2,687,652
Assets value transferred to CENAGAS			7,450,931
Negative IEPS				2,519,126
Total other revenues		32,253,564	91,430,366	19,350,014
Expenses:
Loss in the Assets value transferred to CENAGAS			(35,333,411)
Disposal of assets		(8,447,031)	(2,140,943)	(3,364,063)
Transportation and distribution of natural gas		(6,652,878)	(8,830,967)	(369,317)
Other		(7,927,150)	(3,581,036)	(726,589)
Claims		(3,640,036)	(4,757,116)	(12,527,548)
Loss in the sale of associates		(412,393)	(7,473,698)
Impairment of goodwill			(4,007,018)
Services provided			(2,656,571)	(3,237,984)
Total other expenses		(27,079,488)	(68,780,760)	(20,225,501)
Other revenues and expenses-net		$ 5,174,076	$ 22,649,606	$ (875,487)

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Related Parties - Summary of Ownership Interests (Detail)	Dec. 31, 2017
Servicio Cozumel SA de CV [member] | Pedro Joaquin Coldwell [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	60.00%
Servicio Cozumel SA de CV [member] | Pedro Oscar Joaquin Delbouis [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	20.00%
Servicio Cozumel SA de CV [member] | Nassim Joaquin Delbouis [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	20.00%
Planta de Combustible Cozumel, S. A. de C. V [member] | Pedro Joaquin Coldwell [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	40.00%
Planta de Combustible Cozumel, S. A. de C. V [member] | Fideicomiso Testamentario [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	57.00%
Gasolinera y Servicios Juarez, S. A. de C. V [member] | Pedro Joaquin Coldwell [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	40.00%
Gasolinera y Servicios Juarez, S. A. de C. V [member] | Fideicomiso Testamentario [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	40.00%
Gasolinera y Servicios Juarez, S. A. de C. V [member] | Ignacio Nassim Ruiz Joaquin [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	20.00%
Combustibles Caleta, S. A. de C. V [member] | Pedro Joaquin Coldwell [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	20.00%
Combustibles Caleta, S. A. de C. V [member] | Pedro Oscar Joaquin Delbouis [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	20.00%
Combustibles Caleta, S. A. de C. V [member] | Nassim Joaquin Delbouis [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	20.00%
Combustibles Caleta, S. A. de C. V [member] | Fideicomiso Testamentario [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	20.00%
Combustibles Caleta, S. A. de C. V [member] | Ignacio Nassim Ruiz Joaquin [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	20.00%
Combustibles San Miguel, S. A. de C. V [member] | Pedro Joaquin Coldwell [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	25.00%
Combustibles San Miguel, S. A. de C. V [member] | Pedro Oscar Joaquin Delbouis [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	25.00%
Combustibles San Miguel, S. A. de C. V [member] | Nassim Joaquin Delbouis [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	25.00%
Combustibles San Miguel, S. A. de C. V [member] | Ignacio Nassim Ruiz Joaquin [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	25.00%

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Related Parties - Summary of Ownership Interests (Parenthetical) (Detail)		1 Months Ended
	Jun. 30, 2016	Jun. 30, 2016	Dec. 31, 2017
Planta de Combustible Cozumel, S. A. de C. V [member] | Pedro Joaquin Coldwell [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage			40.00%
Planta de Combustible Cozumel, S. A. de C. V [member] | Pedro Oscar Joaquin Delbouis [member]
Disclosure of transactions between related parties [line items]
Percentage of voting rights exercised		50.00%
Planta de Combustible Cozumel, S. A. de C. V [member] | Nassim Joaquin Delbouis [member]
Disclosure of transactions between related parties [line items]
Percentage of voting rights exercised		50.00%
Planta de Combustible Cozumel, S. A. de C. V [member] | Fausto Nassim JoaquinIbarra [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	60.00%	60.00%
Percentage of shares become property of an investment		57.00%
Gasolinera y Servicios Juarez, S. A. de C. V [member] | Pedro Joaquin Coldwell [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage			40.00%
Percentage of voting rights exercised	100.00%
Gasolinera y Servicios Juarez, S. A. de C. V [member] | Fausto Nassim JoaquinIbarra [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	40.00%	40.00%
Combustibles Caleta, S. A. de C. V [member] | Pedro Joaquin Coldwell [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage			20.00%
Combustibles Caleta, S. A. de C. V [member] | Pedro Oscar Joaquin Delbouis [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage			20.00%
Percentage of voting rights exercised	50.00%
Combustibles Caleta, S. A. de C. V [member] | Nassim Joaquin Delbouis [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage			20.00%
Percentage of voting rights exercised	50.00%
Combustibles Caleta, S. A. de C. V [member] | Fausto Nassim JoaquinIbarra [member]
Disclosure of transactions between related parties [line items]
Ownership share, percentage	20.00%	20.00%

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Related Parties - Additional Information (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of transactions between related parties [abstract]
Aggregate compensation of executive officers	$ 50,749	$ 49,165	$ 116,930
Accrued or paid key management personnel compensation	$ 7,525	8,339	$ 17,899
Salary advance terms	An amount up to a maximum of four months' salary and are repaid through salary deductions in equal installments over a period of either one or two years
Salary advances outstanding	$ 3,466	$ 2,415

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Commitments - Additional information (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Disclosure of commitments [Line Items]
Nitrogen to be supplied			$ 7,506,619	$ 8,646,726
Contract term	25 years	25 years
Contract payments	$ 591,011	$ 11,694,162	15,664,703	$ (51,135,948)
Outstanding contracts payments		0
Northern Region [member]
Disclosure of commitments [Line Items]
Contract payments		6,594,486	7,026,822
Southern Region [member]
Disclosure of commitments [Line Items]
Contract payments		$ 727,331	$ 524,475

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Commitments - Estimated Future Payments Under Contract (Detail) - Nitrogen supply contract [member] $ in Thousands	12 Months Ended
	Dec. 31, 2017 MXN ($)
Commitments and contingencies [Line Items]
2018	$ 773,047
2019	783,197
2020	785,670
2021	786,323
2022	782,584
2023 and thereafter	3,595,798
Total	$ 7,506,619

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Commitments - Estimated Value of Contracts (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Financing performance of works [member]
Commitments and contingencies [Line Items]
Estimated value of contracts	$ 12,403,910	$ 16,513,175
Financing performance of works [member] | 2017 [member]
Commitments and contingencies [Line Items]
Estimated value of contracts	5,533,174	7,366,247
Financing performance of works [member] | 1 to 3 years [member]
Commitments and contingencies [Line Items]
Estimated value of contracts	1,891,557	2,518,207
Financing performance of works [member] | 2021 [member]
Commitments and contingencies [Line Items]
Estimated value of contracts	1,856,006	2,470,878
Financing performance of works [member] | 2022 and thereafter [member]
Commitments and contingencies [Line Items]
Estimated value of contracts	3,123,173	4,157,843
Infrastructure and service works [member]
Commitments and contingencies [Line Items]
Estimated value of contracts	698,905,230	817,994,130
Infrastructure and service works [member] | 2017 [member]
Commitments and contingencies [Line Items]
Estimated value of contracts	229,738,368	347,606,848
Infrastructure and service works [member] | 1 to 3 years [member]
Commitments and contingencies [Line Items]
Estimated value of contracts	196,335,411	281,563,607
Infrastructure and service works [member] | 2021 [member]
Commitments and contingencies [Line Items]
Estimated value of contracts	123,159,215	69,541,826
Infrastructure and service works [member] | 2022 and thereafter [member]
Commitments and contingencies [Line Items]
Estimated value of contracts	$ 149,672,236	$ 119,281,849

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Contingencies - Additional Information (Detail)							1 Months Ended
	Dec. 12, 2017 MXN ($)	Aug. 01, 2017 USD ($)	Aug. 01, 2017 MXN ($)	Jun. 11, 2015 MXN ($)	Jul. 08, 2011 MXN ($)	Apr. 04, 2011 USD ($)	Jun. 30, 2016 USD ($)	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)
Disclosure of contingent liabilities [line items]
Accrued reserve on contingent liabilities									$ 7,812,689,000	$ 15,119,692,000
Legal proceedings damage sought by plaintiffs	$ 153,000,000	$ 12,820	$ 800,000,000	$ 2,094,232,000	$ 1,552,730,000	$ 193,713,000	$ 120,856,000
Contingent Liability for Guarantees [Member] | Exploration [member]
Disclosure of contingent liabilities [line items]
Exploration and evaluation costs								$ 320,000,000
Contingent Liability for Guarantees [Member] | Exploration [member] | Deep Water License Modality Trion Field [Member]
Disclosure of contingent liabilities [line items]
Exploration and evaluation costs								4,000,000,000
Contingent Liability for Guarantees [Member] | Exploration [member] | Cinturon Plegado Perdido [member]
Disclosure of contingent liabilities [line items]
Exploration and evaluation costs								3,333,000,000
Contingent Liability for Guarantees [Member] | Exploration [member] | Ek Balam Fields [member]
Disclosure of contingent liabilities [line items]
Exploration and evaluation costs								5,000,000,000
Contingent Liability for Guarantees [Member] | Exploration [member] | Tampico Misantla [member]
Disclosure of contingent liabilities [line items]
Exploration and evaluation costs								1,750,000,000
Contingent Liability for Guarantees [Member] | Exploration [member] | Cuencas Del Sureste [member]
Disclosure of contingent liabilities [line items]
Exploration and evaluation costs								1,250,000,000
Contingent Liability for Guarantees [Member] | Exploration [member] | Assignment AE Zero Three Nine Eight Mission [member]
Disclosure of contingent liabilities [line items]
Exploration and evaluation costs								255,000,000
Contingent Liability for Guarantees [Member] | Exploration [member] | Ogarrio Field [member]
Disclosure of contingent liabilities [line items]
Exploration and evaluation costs								250,000,000
Contingent Liability for Guarantees [Member] | Exploration [member] | Cardenas And Mora Fields [member]
Disclosure of contingent liabilities [line items]
Exploration and evaluation costs								$ 250,000,000

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Business Combination - Additional Information (Detail) - Fertinal [member] $ in Thousands, $ in Thousands		12 Months Ended
	Jan. 28, 2016 USD ($)	Dec. 31, 2017	Jan. 28, 2016 MXN ($)
Disclosure of detailed information about business combination [line items]
Percentage oustanding shares acquired	99.99%		99.99%
Total purchase price			$ 4,322,826
Credit lines under a simple credit agreement	$ 425,800
Debt maturity period	16 years
Total assets, net			315,808
Goodwill			$ 4,007,018
Percentage of domestic market to cover		50.00%

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Business Combination - Net Fair Value of Assets and Liabilities at Acquisition Date (Detail) - Fertinal [member] $ in Thousands	Jan. 28, 2016 MXN ($)
Disclosure of detailed information about business combination [line items]
Cash and cash equivalents	$ (6,943)
Accounts receivable	102,121
Inventories	762,254
Properties, plant and equipment	9,811,928
Other assets	1,671,718
Total assets	12,341,078
Accounts payable	2,331,540
Debt	9,365,152
Deferred taxes	328,578
Total liabilities	12,025,270
Total assets, net	315,808
Transaction value	4,322,826
Goodwill	$ 4,007,018

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Subsequent Events - Additional Information (Detail) € in Thousands, SFr in Thousands, $ in Thousands, $ in Thousands					1 Months Ended	12 Months Ended
	Apr. 27, 2018 USD ($) $ / $ $ / Barrel	Mar. 05, 2018 USD ($)	Feb. 18, 2018 USD ($)	Feb. 12, 2018 USD ($)	Mar. 31, 2017 USD ($)	Dec. 31, 2017 USD ($) $ / $ $ / Barrel	Dec. 31, 2017 MXN ($) $ / Barrel	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)	Jun. 16, 2017 USD ($)	Jun. 15, 2017 USD ($)	Feb. 14, 2017 EUR (€)	Dec. 13, 2016 USD ($)	Sep. 21, 2016 USD ($)	Jun. 14, 2016 CHF (SFr)	Mar. 15, 2016 USD ($)	Mar. 15, 2016 EUR (€)	Feb. 04, 2016 USD ($)
Disclosure of non-adjusting events after reporting period [line items]
Debt securities issued			$ 4,000,000
Repayment of revolving credit lines						$ 32,342,434	$ 642,059,819	$ 614,987,329	$ 193,618,498
Exchange rates | $ / $						19.7867
Weighted average price of crude oil | $ / Barrel						56.19	56.19
Damage claimed					$ 139,870
P.M.I. Holdings, B.V. [member]
Disclosure of non-adjusting events after reporting period [line items]
Repayment of revolving credit lines						$ 14,914,000
Outstanding of revolving credit lines						$ 227,500
Series C medium term notes program [member]
Disclosure of non-adjusting events after reporting period [line items]
Debt securities issued			92,000,000							$ 92,000,000	$ 72,000,000	€ 4,250,000	$ 5,500,000	$ 62,000,000	SFr 375,000	$ 62,000,000	€ 2,250,000	$ 5,000,000
Subsequent Event [member]
Disclosure of non-adjusting events after reporting period [line items]
Exchange rates | $ / $	19.0530
Appreciation of foreign currency exchange rate	3.70%
Weighted average price of crude oil | $ / Barrel	60.89
Percentage of average price	8.30%
Subsequent Event [member] | P.M.I. Holdings, B.V. [member]
Disclosure of non-adjusting events after reporting period [line items]
Obtain of revolving credit lines	$ 7,126,000
Repayment of revolving credit lines	6,126,000
Outstanding of revolving credit lines	$ 1,227,500
Five Point Three Five Percentage Notes Due Twenty Twenty Eight [member] | Series C medium term notes program [member]
Disclosure of non-adjusting events after reporting period [line items]
Debt securities issued			$ 2,500,000,000
Interest rate			5.35%
Maturity			2028
Six Point Three Five Percentage Notes Due Twenty Fourty Eight [Member] | Series C medium term notes program [member]
Disclosure of non-adjusting events after reporting period [line items]
Interest rate			6.35%
Maturity			2048
Bonds issued			$ 1,500,000,000
Five Point Five Zero Zero Percentage Bonds Due Twenty Fourty Four [Member] | Series C medium term notes program [member]
Disclosure of non-adjusting events after reporting period [line items]
Interest rate				5.50%
Maturity				2044
Bonds exchanged amount				$ 952,454
New Six Point Three Five Zero Percentage Bonds Due Twenty Fourty Eight [Member] | Series C medium term notes program [member]
Disclosure of non-adjusting events after reporting period [line items]
Interest rate				6.35%
Maturity				2048
Bonds exchanged amount				$ 881,899
Five Point Six Two Five Percentage Bonds Due Twenty Fourty Six [Member] | Series C medium term notes program [member]
Disclosure of non-adjusting events after reporting period [line items]
Interest rate				5.625%
Maturity				2046
Bonds exchanged amount				$ 1,021,065
Six Point Three Five Percentage Bonds Due Twenty Fourty Eight [Member] | Series C medium term notes program [member]
Disclosure of non-adjusting events after reporting period [line items]
Interest rate				6.35%
Maturity				2048
Bonds exchanged amount				$ 946,764
Three Point One Two Five Percentage Bonds Repurchased Due Twenty Ninteen [Member]
Disclosure of non-adjusting events after reporting period [line items]
Interest rate		3.125%
Maturity		2019
Bonds purchased		$ 138,598
Five Point Five Zero Zero Percentage Bonds Repurchased Due Twenty Ninteen [Member]
Disclosure of non-adjusting events after reporting period [line items]
Interest rate		5.50%
Maturity		2019
Bonds purchased		$ 558,644
Eight Point Zero Zero Zero Percentage Bonds Repurchased Due Twenty Ninteen [Member]
Disclosure of non-adjusting events after reporting period [line items]
Interest rate		8.00%
Maturity		2019
Bonds purchased		$ 91,843
Six Point Zero Zero Zero Percentage Bonds Repurchased Due Twenty Twenty [Member]
Disclosure of non-adjusting events after reporting period [line items]
Interest rate		6.00%
Maturity		2020
Bonds purchased		$ 183,017
Three Point Five Zero Zero Percentage Bonds Repurchased Due Twenty Twenty [Member]
Disclosure of non-adjusting events after reporting period [line items]
Interest rate		3.50%
Maturity		2020
Bonds purchased		$ 817,303

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Subsidiary Guarantor Information - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2017
Disclosure of subsidiaries [abstract]
Percentage of owned guarantors subsidiaries	100.00%

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Subsidiary Guarantor Information - Summary of Principal Amount Outstanding of Registered Debt Securities (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)
5.75% Guaranteed Notes due 2018 [member] | Master Trust [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 834,688
6.625% Guaranteed Bonds due 2035 [member] | Master Trust [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 1,750,000
6.625% Guaranteed Bonds due 2038 [member] | Master Trust [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 491,175
8.625% Bonds due 2022 [member] | Master Trust [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 160,245
8.625% Guaranteed Bonds due 2023 [member] | Master Trust [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 106,507
91/4% Guaranteed Bonds due 2018 [member] | Master Trust [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 107,109
9.50% Guaranteed Bonds due 2027 [member] | Master Trust [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 219,217
8.00% Notes due 2019 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 1,312,015
3.500% Notes due 2018 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 355,356
9.50% Global Guaranteed Bonds due 2027 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 102,149
Floating Rate Notes due 2018 member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 498,570
6.000% Notes due 2020 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 995,364
5.50% Notes due 2021 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 2,962,047
3.500% Notes due 2023 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 2,099,730
4.875% Notes due 2024 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 1,499,136
6.625% Notes due 2035 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 999,000
6.500% Bonds due 2041 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 3,000,000
4.875% Bonds 2022 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 2,097,055
3.125% Notes due 2019 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 325,778
3.500% Notes due 2020 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 1,465,367
5.50% Bonds due 2044 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 2,657,962
6.375% Bonds due en 2045 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 2,999,980
5.625% Bonds due 2046 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 2,996,226
4.500% Notes due 2026 member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 1,489,718
4.250% Notes due 2025 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 998,435
Five point five percent guaranteed notes due two thousand nineteen [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 740,851
Six point three seven five percent guaranteed notes due two thousand twenty one [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 1,247,668
Six point eight seven five percent guaranteed notes due two thousand twenty six [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 2,970,334
Four point six two five percent guaranteed notes due two thousand twenty three [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 2,055,498
Six point seven five percent guaranteed notes due two thousand forty seven [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 3,671,628
9.250% global guaranteed bonds due 2028 [member] | Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Issuer	Petróleos Mexicanos
Guarantors	Pemex Exploration and Production, Pemex Industrial Transformation, Pemex Drilling and Services, Pemex Logistics and Pemex Cogeneration and Services
Principal amount outstanding (U.S. $)	$ 9,296

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Subsidiary Guarantor Information - Supplemental Statement of Financial Position (Detail) $ in Thousands, $ in Thousands	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)	Dec. 31, 2014 MXN ($)
Current assets
Cash and cash equivalents	$ 4,945,330	$ 97,851,754	$ 8,264,769	$ 163,532,513	$ 109,368,880	$ 117,988,528
Accounts receivable and other, net, and derivative financial instruments		200,758,688		138,077,997
Inventories	3,227,366	63,858,930		45,892,060
Available-for-sale financial assets	53,416	1,056,918		2,852,679
Held-for-sale non-financial assets		1,056,918		7,460,674
Total current assets	18,372,255	363,526,290		357,815,923	267,200,497
Available-for-sale financial assets				6,027,540
Investments in joint ventures and associates	844,373	16,707,364		20,737,509	24,165,599
Wells, pipelines, properties, plant and equipment-net	72,599,743	1,436,509,326		1,667,742,248	1,344,483,631
Long-term notes receivables	7,504,683	148,492,909		148,607,602
Deferred taxes	7,388,422	146,192,485		100,324,689
Restricted cash				10,478,626
Intangible assets	459,327	9,088,563		8,639,242
Other assets	580,449	11,485,177		9,512,645
Total assets	107,749,252	2,132,002,114		2,329,886,024	1,775,654,200
Current liabilities
Current portion of long-term debt	7,945,209	157,209,467		176,166,188
Other current liabilities		231,917,718		250,023,698
Total current liabilities	19,666,099	389,127,185		426,189,886	443,407,721
Long-term debt	95,046,956	1,880,665,604		1,807,004,542	1,300,873,167
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		1,364,561,710		1,329,699,743
Total liabilities	183,676,636	3,634,354,499		3,562,894,171	3,107,330,098
Long-term debt	95,046,956	1,880,665,604		1,807,004,542	1,300,873,167
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		1,364,561,710		1,329,699,743
Total liabilities	183,676,636	3,634,354,499		3,562,894,171	3,107,330,098
Equity (deficit), net	(75,927,384)	(1,502,352,385)		(1,233,008,147)	(1,331,675,898)	(767,720,854)
Total liabilities and equity	$ 107,749,252	2,132,002,114		2,329,886,024
Petroleos Mexicanos [member]
Current assets
Cash and cash equivalents		46,959,103		92,503,607	58,461,014	73,002,640
Accounts receivable and other, net, and derivative financial instruments		83,119,394		6,604,595
Accounts receivable-inter-company		311,148,593		440,645,367
Inventories		509,375		446,954
Total current assets		441,736,465		540,200,523
Long-term receivables-intercompany		1,823,276,758		1,740,519,399
Investments in joint ventures and associates		(465,832,399)		(250,108,630)
Wells, pipelines, properties, plant and equipment-net		12,444,376		12,596,722
Long-term notes receivables		147,286,367		140,579,974
Deferred taxes		59,691,528		59,162,878
Other assets		2,209,579		1,824,104
Total assets		2,020,812,674		2,244,774,970
Current liabilities
Current portion of long-term debt		137,947,110		157,937,631
Accounts payable-inter-company		1,240,490,891		1,265,244,986
Other current liabilities		23,435,614		34,913,773
Total current liabilities		1,401,873,615		1,458,096,390
Long-term debt		1,824,829,579		1,737,332,174
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		297,028,436		282,902,667
Total liabilities		3,523,731,630		3,478,331,231
Long-term debt		1,824,829,579		1,737,332,174
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		297,028,436		282,902,667
Total liabilities		3,523,731,630		3,478,331,231
Equity (deficit), net		(1,502,918,956)		(1,233,556,261)
Total liabilities and equity		2,020,812,674		2,244,774,970
Subsidiary guarantors [member]
Current assets
Cash and cash equivalents		18,815,345		9,732,503	6,630,674	5,407,420
Accounts receivable and other, net, and derivative financial instruments		38,105,354		75,760,079
Accounts receivable-inter-company		1,380,100,592		1,684,782,235
Inventories		32,357,125		29,270,943
Held-for-sale non-financial assets				7,460,674
Total current assets		1,469,378,416		1,807,006,434
Long-term receivables-intercompany		285		289
Investments in joint ventures and associates		82,668		396,681
Wells, pipelines, properties, plant and equipment-net		1,370,974,060		1,595,655,580
Long-term notes receivables		1,206,542		8,027,628
Deferred taxes		84,443,897		40,341,615
Restricted cash				9,624,804
Intangible assets		9,088,563		8,639,242
Other assets		4,846,078		2,707,788
Total assets		2,940,020,509		3,472,400,061
Current liabilities
Current portion of long-term debt		5,386,564		7,381,095
Accounts payable-inter-company		434,556,688		854,106,939
Other current liabilities		157,589,107		169,182,239
Total current liabilities		597,532,359		1,030,670,273
Long-term debt		40,262,391		46,090,919
Long-term payables-inter-company		1,830,150,615		1,746,433,870
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		1,057,191,286		1,035,019,339
Total liabilities		3,525,136,651		3,858,214,401
Long-term debt		40,262,391		46,090,919
Long-term payables-inter-company		1,830,150,615		1,746,433,870
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		1,057,191,286		1,035,019,339
Total liabilities		3,525,136,651		3,858,214,401
Equity (deficit), net		(585,116,142)		(385,814,340)
Total liabilities and equity		2,940,020,509		3,472,400,061
Non-guarantor subsidiaries [member]
Current assets
Cash and cash equivalents		32,077,306		61,296,403	$ 44,277,192	$ 39,578,468
Accounts receivable and other, net, and derivative financial instruments		79,533,940		55,713,323
Accounts receivable-inter-company		86,354,837		70,268,246
Inventories		30,992,430		16,174,163
Available-for-sale financial assets		1,056,918		2,852,679
Total current assets		230,015,431		206,304,814
Available-for-sale financial assets				6,027,540
Long-term receivables-intercompany		3,597,880		6,384,944
Investments in joint ventures and associates		16,611,681		20,327,813
Wells, pipelines, properties, plant and equipment-net		53,090,890		59,489,946
Deferred taxes		2,057,060		820,196
Restricted cash				853,822
Other assets		4,429,520		4,980,753
Total assets		309,802,462		305,189,828
Current liabilities
Current portion of long-term debt		13,875,793		10,847,462
Accounts payable-inter-company		93,140,905		68,510,835
Other current liabilities		50,892,997		45,927,686
Total current liabilities		157,909,695		125,285,983
Long-term debt		15,573,634		23,581,449
Long-term payables-inter-company		6,139,845		8,303,850
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		10,341,988		11,777,737
Total liabilities		189,965,162		168,949,019
Long-term debt		15,573,634		23,581,449
Long-term payables-inter-company		6,139,845		8,303,850
Employee benefits, provisions for sundry creditors, other liabilities and deferred taxes		10,341,988		11,777,737
Total liabilities		189,965,162		168,949,019
Equity (deficit), net		119,837,300		136,240,809
Total liabilities and equity		309,802,462		305,189,828
Intersegment Eliminations [member]
Current assets
Accounts receivable-inter-company		(1,777,604,022)		(2,195,695,848)
Total current assets		(1,777,604,022)		(2,195,695,848)
Long-term receivables-intercompany		(1,826,874,923)		(1,746,904,632)
Investments in joint ventures and associates		465,845,414		250,121,645
Total assets		(3,138,633,531)		(3,692,478,835)
Current liabilities
Accounts payable-inter-company		(1,768,188,484)		(2,187,862,760)
Total current liabilities		(1,768,188,484)		(2,187,862,760)
Long-term payables-inter-company		(1,836,290,460)		(1,754,737,720)
Total liabilities		(3,604,478,944)		(3,942,600,480)
Long-term payables-inter-company		(1,836,290,460)		(1,754,737,720)
Total liabilities		(3,604,478,944)		(3,942,600,480)
Equity (deficit), net		465,845,413		250,121,645
Total liabilities and equity		$ (3,138,633,531)		$ (3,692,478,835)

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Subsidiary Guarantor Information - Supplemental Statement of Comprehensive Income (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Supplemental Information [Line Items]
Net sales		$ 1,385,899,150	$ 1,065,118,590	$ 1,153,450,357
Services income	$ 562,528	11,130,569	8,974,642	8,310,035
Total of sales	70,604,483	1,397,029,719	1,074,093,232	1,161,760,392
Impairment (reversal) of wells, pipelines, properties, plant and equipment	7,653,856	151,444,560	(331,314,343)	477,944,690
Benefit from change in pension plan				(92,177,089)
Cost of sales	50,751,509	1,004,204,880	865,822,221	891,964,606
Gross income	12,199,118	241,380,279	539,585,354	(115,971,815)
Other (expenses) revenues, net	261,493	5,174,076	22,649,606	(875,487)
General expenses:
Transportation, distribution and sale expenses	1,106,282	21,889,670	25,231,240	28,928,639
Administrative expenses	6,061,620	119,939,454	112,653,533	112,472,095
Benefit from change in pension plan				(103,860,955)
Total general expenses		141,829,124	137,884,773	37,539,779
Transportation, distribution and sale expenses	1,106,282	21,889,670	25,231,240	28,928,639
Administrative expenses	6,061,620	119,939,454	112,653,533	112,472,095
Total general expenses		141,829,124	137,884,773	37,539,779
Operating income	5,292,708	104,725,231	424,350,187	(154,387,081)
Financing income	817,006	16,165,853	13,749,255	14,990,859
Financing cost	5,945,638	117,644,548	98,844,464	67,773,593
Derivative financial instruments (cost) income, net		25,338,324	(14,000,987)	(21,449,877)
Foreign exchange income (loss), net	1,171,702	23,184,122	(254,012,743)	(154,765,574)
(Loss) profit sharing in joint ventures and associates	18,216	360,440	2,135,845	2,318,115
Income (loss) before taxes, duties and other	2,634,569	52,129,422	73,377,093	(381,067,151)
Total taxes, duties and other	16,828,478	332,980,041	264,521,435	331,500,247
Net (loss) income for the year	(14,193,909)	(280,850,619)	(191,144,342)	(712,567,398)
Total other comprehensive result	581,521	11,506,381	127,872,481	88,612,354
Total comprehensive result for the year	$ (13,612,388)	(269,344,238)	(63,271,861)	(623,955,044)
Petroleos Mexicanos [member]
Supplemental Information [Line Items]
Net sales				15,556
Services income		50,399,983	46,330,245	16,897,139
Total of sales		50,399,983	46,330,245	16,912,695
Cost of sales		2,007,814	1,236,921	2,695,423
Gross income		48,392,169	45,093,324	14,217,272
Other (expenses) revenues, net		(341,521)	(312,611)	(19,805)
General expenses:
Administrative expenses		59,141,391	57,437,455	59,923,878
Benefit from change in pension plan				(46,031,780)
Total general expenses		59,141,391	57,437,455	13,892,098
Administrative expenses		59,141,391	57,437,455	59,923,878
Total general expenses		59,141,391	57,437,455	13,892,098
Operating income		(11,090,743)	(12,656,742)	305,369
Financing income		143,676,367	123,266,281	108,543,665
Financing cost		(236,929,035)	160,824,632	85,544,060
Derivative financial instruments (cost) income, net		27,670,991	(12,052,200)	(22,803,663)
Foreign exchange income (loss), net		6,837,171	(20,531,005)	(14,829,436)
(Loss) profit sharing in joint ventures and associates		(211,567,169)	(117,347,803)	(749,963,960)
Income (loss) before taxes, duties and other		(281,402,418)	(200,146,101)	(764,292,085)
Total taxes, duties and other		(557,520)	(8,834,626)	(51,982,560)
Net (loss) income for the year		(280,844,898)	(191,311,475)	(712,309,525)
Total other comprehensive result		4,728,640	10,126,560	10,980,787
Total comprehensive result for the year		(276,116,258)	(181,184,915)	(701,328,738)
Subsidiary guarantors [member]
Supplemental Information [Line Items]
Net sales		1,713,914,703	1,361,538,624	1,523,767,800
Services income		140,934,022	98,959,131	16,815,589
Total of sales		1,854,848,725	1,460,497,755	1,540,583,389
Impairment (reversal) of wells, pipelines, properties, plant and equipment		145,302,407	(330,037,834)	476,276,159
Benefit from change in pension plan				(83,657,496)
Cost of sales		1,447,640,131	1,244,388,072	1,280,404,059
Gross income		261,906,187	546,147,517	(132,439,333)
Other (expenses) revenues, net		(12,443,660)	20,713,184	(6,073,003)
General expenses:
Transportation, distribution and sale expenses		26,136,674	50,948,771	32,870,908
Administrative expenses		105,920,390	96,884,031	52,832,029
Benefit from change in pension plan				(50,394,477)
Total general expenses		132,057,064	147,832,802	35,308,460
Transportation, distribution and sale expenses		26,136,674	50,948,771	32,870,908
Administrative expenses		105,920,390	96,884,031	52,832,029
Total general expenses		132,057,064	147,832,802	35,308,460
Operating income		117,405,463	419,027,899	(173,820,796)
Financing income		134,401,598	67,542,768	28,639,034
Financing cost		(141,900,236)	114,271,762	104,453,148
Derivative financial instruments (cost) income, net		(1,608,039)	3,172	6,463
Foreign exchange income (loss), net		15,807,988	(232,714,446)	(139,623,910)
(Loss) profit sharing in joint ventures and associates		409,955	628,357	198,786
Income (loss) before taxes, duties and other		124,516,729	140,215,988	(389,053,571)
Total taxes, duties and other		331,001,261	266,155,181	376,649,369
Net (loss) income for the year		(206,484,532)	(125,939,193)	(765,702,940)
Total other comprehensive result		6,841,586	96,032,433	56,585,790
Total comprehensive result for the year		(199,642,946)	(29,906,760)	(709,117,150)
Non-guarantor subsidiaries [member]
Supplemental Information [Line Items]
Net sales		1,096,752,930	828,143,332	803,623,324
Services income		2,646,144	1,970,055	2,585,617
Total of sales		1,099,399,074	830,113,387	806,208,941
Impairment (reversal) of wells, pipelines, properties, plant and equipment		6,142,153	(1,276,509)	1,668,531
Benefit from change in pension plan				(8,519,593)
Cost of sales		1,083,297,610	809,156,778	791,147,745
Gross income		9,959,311	22,233,118	21,912,258
Other (expenses) revenues, net		(4,664,096)	2,915,837	3,326,421
General expenses:
Transportation, distribution and sale expenses		1,297,558	945,489	2,921,430
Administrative expenses		5,883,200	7,050,271	10,638,127
Benefit from change in pension plan				(7,434,698)
Total general expenses		7,180,758	7,995,760	6,124,859
Transportation, distribution and sale expenses		1,297,558	945,489	2,921,430
Administrative expenses		5,883,200	7,050,271	10,638,127
Total general expenses		7,180,758	7,995,760	6,124,859
Operating income		(1,885,543)	17,153,195	19,113,820
Financing income		3,185,195	3,526,378	3,478,434
Financing cost		(3,616,530)	3,602,868	3,306,776
Derivative financial instruments (cost) income, net		(724,628)	(1,951,959)	1,347,323
Foreign exchange income (loss), net		538,963	(767,292)	(312,228)
(Loss) profit sharing in joint ventures and associates		(49,515)	1,507,488	2,119,329
Income (loss) before taxes, duties and other		(2,552,058)	15,864,942	22,439,902
Total taxes, duties and other		2,536,300	7,200,880	6,833,438
Net (loss) income for the year		(5,088,358)	8,664,062	15,606,464
Total other comprehensive result		(63,845)	21,713,488	21,045,777
Total comprehensive result for the year		(5,152,203)	30,377,550	36,652,241
Intersegment Eliminations [member]
Supplemental Information [Line Items]
Net sales		(1,424,768,483)	(1,124,563,366)	(1,173,956,323)
Services income		(182,849,580)	(138,284,789)	(27,988,310)
Total of sales		(1,607,618,063)	(1,262,848,155)	(1,201,944,633)
Cost of sales		(1,528,740,675)	(1,188,959,550)	(1,182,282,621)
Gross income		(78,877,388)	(73,888,605)	(19,662,012)
Other (expenses) revenues, net		22,623,353	(666,804)	1,890,900
General expenses:
Transportation, distribution and sale expenses		(5,544,562)	(26,663,020)	(6,863,699)
Administrative expenses		(51,005,527)	(48,718,224)	(10,921,939)
Total general expenses		(56,550,089)	(75,381,244)	(17,785,638)
Transportation, distribution and sale expenses		(5,544,562)	(26,663,020)	(6,863,699)
Administrative expenses		(51,005,527)	(48,718,224)	(10,921,939)
Total general expenses		(56,550,089)	(75,381,244)	(17,785,638)
Operating income		296,054	825,835	14,526
Financing income		(265,097,307)	(180,586,172)	(125,670,274)
Financing cost		264,801,253	(179,854,798)	(125,530,391)
(Loss) profit sharing in joint ventures and associates		211,567,169	117,347,803	749,963,960
Income (loss) before taxes, duties and other		211,567,169	117,442,264	749,838,603
Net (loss) income for the year		211,567,169	117,442,264	749,838,603
Total comprehensive result for the year		$ 211,567,169	$ 117,442,264	$ 749,838,603

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Subsidiary Guarantor Information - Supplemental Statement of Cash Flows (Detail) $ in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2017 MXN ($)	Dec. 31, 2016 MXN ($)	Dec. 31, 2015 MXN ($)
Operating activities:
Net (loss) income for the year		$ (280,850,619)	$ (191,144,342)	$ (712,567,398)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization	$ 7,919,689	156,704,513	150,439,491	167,951,250
(Reversal) impairment of wells, pipelines, properties, plant and equipment	7,653,856	151,444,560	(331,314,343)	477,944,690
Unsuccessful wells	311,554	6,164,624	29,106,084	23,213,519
Exploration costs		(1,447,761)	(2,022,826)	(5,698,511)
Disposal of wells, pipelines, properties, plant and equipment	862,381	17,063,671	3,771,287	24,638,537
Loss in sale of fixed assets			27,882,480
Gain on sale of share in joint ventures and associates	(158,647)	(3,139,103)	(15,211,039)	(680,630)
Profit (loss) sharing in joint ventures and associates			(2,135,845)	(2,318,115)
Disposal of held-for-sale current non-financial assets		2,808,360
Impairment of goodwill			4,007,018
Dividends	(9,131)	(180,675)	(293,397)	(359,941)
Effects of net present value of reserve for well abandonment	392,890	7,774,000	11,968,966	(608,160)
Profit (loss) sharing in investments		(360,440)
Decrease on available-for-sale financial assets	68,743	1,360,205
Net loss on available-for-sale financial assets	178,087	3,523,748
Unrealized foreign exchange loss (gain)	(843,265)	(16,685,439)	243,182,764	152,676,256
Interest expense	5,945,638	117,644,548	98,844,464	67,773,593
Accounts receivable, accounts payable and derivative financial instruments		(123,501,225)	(89,784,505)	33,429,565
Inventories	(908,028)	(17,966,870)	(1,358,879)	6,167,728
Other assets		(7,024,023)	(25,128,530)	(16,602,365)
Employee benefits	2,530,255	50,065,396	47,293,069	(116,022,232)
Net cash flows from (used in) operating activities	3,204,044	63,397,470	(41,898,083)	98,937,786
Acquisition of wells, pipelines, properties, plant and equipment	(4,642,485)	(91,859,465)	(151,408,480)	(253,514,001)
Investments in associates				(36,214)
Resources from sale of shares in associates	158,779	3,141,710	22,684,736	4,417,138
Cash flows used in investing activities	(4,078,038)	(80,690,919)	(132,492,848)	(249,133,077)
Resources from sale available-for-sale financial assets	405,668	8,026,836
Proceeds from the sale of fixed assets			560,665
Business acquisition			(4,329,769)
Financing activities:
Increase in equity due to Certificates of Contributions "A"			73,500,000	10,000,000
Loans obtained from financial institutions	35,615,614	704,715,468	841,991,767	378,971,078
Debt payments, principal only	(32,342,434)	(642,059,819)	(614,987,329)	(193,618,498)
Interest paid	(5,504,223)	(108,910,417)	(88,754,141)	(62,737,150)
Cash flows provided by financing activities:	(2,231,043)	(46,254,768)	211,750,297	132,615,430
Cash flows provided by financing activities:	(2,231,043)	(46,254,768)	211,750,297	132,615,430
Net (decrease) increase in cash and cash equivalents	(3,211,663)	(63,548,217)	37,359,366	(17,579,861)
Effects of change in cash value	(107,776)	(2,132,542)	16,804,267	8,960,213
Cash and cash equivalents at the beginning of the year	8,264,769	163,532,513	109,368,880	117,988,528
Cash and cash equivalents at the end of the year	$ 4,945,330	97,851,754	163,532,513	109,368,880
Petroleos Mexicanos [member]
Operating activities:
Net (loss) income for the year		(280,844,898)	(191,311,476)	(712,177,124)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization		1,155,881	1,066,033	789,657
Disposal of wells, pipelines, properties, plant and equipment		433,391	320,599	180,992
Profit (loss) sharing in joint ventures and associates			117,249,643	749,963,958
Profit (loss) sharing in investments		211,567,169
Unrealized foreign exchange loss (gain)		(13,526,153)	231,191,646	145,971,158
Interest expense		100,545,114	91,044,541	63,460,443
Accounts receivable, accounts payable and derivative financial instruments		(88,496,967)	23,636,331	(58,554,144)
Inventories		(62,421)	83,317	108,568
Other assets		(7,091,867)	(2,405,412)	(149,819)
Employee benefits		18,829,768	2,591,000	(10,037,444)
Inter-company charges and deductions		7,284,124	(393,835,932)	(310,384,820)
Net cash flows from (used in) operating activities		(50,206,859)	(120,369,710)	(130,828,575)
Acquisition of wells, pipelines, properties, plant and equipment		(1,436,926)	(2,172,586)	(1,496,277)
(Increase) decrease due to Inter-company investing		25,611,359	(39,612,699)	(39,108,879)
Cash flows used in investing activities		24,174,433	(41,785,285)	(40,605,156)
Financing activities:
Increase in equity due to Certificates of Contributions "A"			73,500,000	10,000,000
Loans obtained from financial institutions		401,947,349	571,944,209	345,383,990
Debt payments, principal only		(327,703,729)	(372,809,166)	(147,927,857)
Interest paid		(93,755,698)	(82,008,347)	(58,123,368)
Inter-company increase (decrease) financing				(3,626,448)
Cash flows provided by financing activities:		(19,512,078)	190,626,696	145,706,317
Cash flows provided by financing activities:		(19,512,078)	190,626,696	145,706,317
Net (decrease) increase in cash and cash equivalents		(45,544,504)	28,471,701	(25,727,414)
Effects of change in cash value			5,570,892	11,185,788
Cash and cash equivalents at the beginning of the year		92,503,607	58,461,014	73,002,640
Cash and cash equivalents at the end of the year		46,959,103	92,503,607	58,461,014
Subsidiary guarantors [member]
Operating activities:
Net (loss) income for the year		(206,484,532)	(139,410,398)	(765,702,826)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization		152,607,943	146,545,307	164,221,429
(Reversal) impairment of wells, pipelines, properties, plant and equipment		145,302,407	(330,037,834)	476,276,159
Unsuccessful wells		6,164,624	29,106,084	23,213,519
Exploration costs		(1,447,761)	(2,022,826)	(5,698,511)
Disposal of wells, pipelines, properties, plant and equipment		14,687,229	2,658,625	21,945,266
Loss in sale of fixed assets			27,882,480
Gain on sale of share in joint ventures and associates		(3,139,103)	(15,211,039)	(337,675)
Profit (loss) sharing in joint ventures and associates			(628,356)	(198,786)
Disposal of held-for-sale current non-financial assets		2,808,360
Effects of net present value of reserve for well abandonment		7,774,000	11,968,966	(608,160)
Profit (loss) sharing in investments		(409,955)
Unrealized foreign exchange loss (gain)		(1,585,910)	6,754,046	2,996,219
Interest expense		15,736,420	5,687,502	3,414,430
Accounts receivable, accounts payable and derivative financial instruments		(14,214,566)	(158,449,370)	119,761,648
Inventories		(3,086,181)	3,508,494	4,547,843
Other assets		(483,389)	(22,600,504)	(16,578,827)
Employee benefits		31,489,785	136,354,337	(94,183,192)
Inter-company charges and deductions		(114,968,213)	(83,049,125)	30,044,041
Net cash flows from (used in) operating activities		30,751,158	(380,943,611)	(36,887,423)
Acquisition of wells, pipelines, properties, plant and equipment		(87,274,561)	(147,786,686)	(239,315,507)
Resources from sale of shares in associates		3,863,072	23,050,344	(130,323)
Cash flows used in investing activities		(83,411,489)	(124,175,677)	(239,445,830)
Proceeds from the sale of fixed assets			560,665
Financing activities:
Increase in equity due to Certificates of Contributions "A"				(1,915,922)
Loans obtained from financial institutions			34,483,348
Debt payments, principal only		(7,981,937)	(6,414,441)	(8,081,177)
Interest paid		(13,991,633)	(4,706,946)	(3,443,923)
Inter-company increase (decrease) financing		83,716,743	464,488,030	289,859,173
Cash flows provided by financing activities:		61,743,173	487,849,991	276,418,151
Cash flows provided by financing activities:		61,743,173	487,849,991	276,418,151
Net (decrease) increase in cash and cash equivalents		9,082,842	(17,269,297)	84,898
Effects of change in cash value			20,371,126	1,138,356
Cash and cash equivalents at the beginning of the year		9,732,503	6,630,674	5,407,420
Cash and cash equivalents at the end of the year		18,815,345	9,732,503	6,630,674
Non-guarantor subsidiaries [member]
Operating activities:
Net (loss) income for the year		(5,082,639)	22,160,755	15,738,868
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization		2,940,689	2,828,151	2,940,164
(Reversal) impairment of wells, pipelines, properties, plant and equipment		6,142,153	(1,276,509)	1,668,531
Disposal of wells, pipelines, properties, plant and equipment		1,943,051	792,063	2,512,279
Gain on sale of share in joint ventures and associates				(342,955)
Profit (loss) sharing in joint ventures and associates			(1,507,489)	(2,119,329)
Impairment of goodwill			4,007,018
Dividends		(180,675)	(293,397)	(359,941)
Profit (loss) sharing in investments		49,515
Decrease on available-for-sale financial assets		1,360,205
Net loss on available-for-sale financial assets		3,523,748
Unrealized foreign exchange loss (gain)		(1,573,376)	5,237,072	3,708,879
Interest expense		1,363,014	2,112,421	898,720
Accounts receivable, accounts payable and derivative financial instruments		(20,789,692)	45,028,534	(27,777,939)
Inventories		(14,818,268)	(4,950,690)	1,511,317
Other assets		551,233	(122,614)	126,281
Employee benefits		(254,157)	(91,652,268)	(11,801,596)
Inter-company charges and deductions		514,270	48,435,633	31,975,215
Net cash flows from (used in) operating activities		(24,310,929)	30,798,680	18,678,494
Acquisition of wells, pipelines, properties, plant and equipment		(3,147,978)	(1,449,208)	(12,702,217)
Investments in associates				(36,214)
Resources from sale of shares in associates		(721,362)	(365,608)	4,547,461
Cash flows used in investing activities		4,157,496	(6,144,585)	(8,190,970)
Resources from sale available-for-sale financial assets		8,026,836
Business acquisition			(4,329,769)
Financing activities:
Increase in equity due to Certificates of Contributions "A"				1,844,394
Loans obtained from financial institutions		302,768,119	235,564,210	33,587,088
Debt payments, principal only		(306,374,153)	(235,763,722)	(37,609,464)
Interest paid		(1,163,086)	(2,038,848)	(1,169,859)
Inter-company increase (decrease) financing		(2,164,002)	3,741,227	922,972
Cash flows provided by financing activities:		(6,933,122)	1,502,867	(2,424,869)
Cash flows provided by financing activities:		(6,933,122)	1,502,867	(2,424,869)
Net (decrease) increase in cash and cash equivalents		(27,086,555)	26,156,962	8,062,655
Effects of change in cash value		(2,132,542)	(9,137,751)	(3,363,931)
Cash and cash equivalents at the beginning of the year		61,296,403	44,277,192	39,578,468
Cash and cash equivalents at the end of the year		32,077,306	61,296,403	44,277,192
Intersegment Eliminations [member]
Operating activities:
Net (loss) income for the year		211,561,450	117,416,777	749,573,684
Adjustments to reconcile net loss to cash provided by operating activities:
Profit (loss) sharing in joint ventures and associates			(117,249,643)	(749,963,958)
Profit (loss) sharing in investments		(211,567,169)
Inter-company charges and deductions		107,169,819	428,449,424	248,365,564
Net cash flows from (used in) operating activities		107,164,100	428,616,558	247,975,290
(Increase) decrease due to Inter-company investing		(25,611,359)	39,612,699	39,108,879
Cash flows used in investing activities		(25,611,359)	39,612,699	39,108,879
Financing activities:
Increase in equity due to Certificates of Contributions "A"				71,528
Inter-company increase (decrease) financing		(81,552,741)	(468,229,257)	(287,155,697)
Cash flows provided by financing activities:		(81,552,741)	(468,229,257)	(287,084,169)
Cash flows provided by financing activities:		$ (81,552,741)	$ (468,229,257)	$ (287,084,169)

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Supplementary Information on Oil and Gas Exploration and Production Activities (Unaudited) - Summary of Capitalized Costs for Oil and Gas Producing Activities (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure Of Oil And Gas Producing Activities [Line Items]
Net capitalized costs	$ 953,755,253	$ 1,181,853,614	$ 966,986,487
Proved reserves [member]
Disclosure Of Oil And Gas Producing Activities [Line Items]
Net capitalized costs	2,363,336,481	2,476,535,503	2,102,971,025
Construction in progress [member]
Disclosure Of Oil And Gas Producing Activities [Line Items]
Net capitalized costs	35,381,089	60,720,261	88,706,330
Accumulated depreciation and amortization [member]
Disclosure Of Oil And Gas Producing Activities [Line Items]
Net capitalized costs	$ (1,444,962,317)	$ (1,355,402,150)	$ (1,224,690,867)

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Supplementary Information on Oil and Gas Exploration and Production Activities (Unaudited) - Summary of Costs Incurred for Oil and Gas Property Exploration and Development Activities (Detail) - MXN ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Disclosure Of Oil And Gas Producing Activities [Line Items]
Total costs incurred	$ 85,941,165	$ 155,556,912
Exploration [member]
Disclosure Of Oil And Gas Producing Activities [Line Items]
Total costs incurred	32,480,801	41,661,666
Development [member]
Disclosure Of Oil And Gas Producing Activities [Line Items]
Total costs incurred	$ 53,460,364	$ 113,895,246

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Supplementary Information on Oil and Gas Exploration and Production Activities (Unaudited) - Additional Information (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2017 MXN ($) Bcf MMBbls	Dec. 31, 2016 MXN ($) Bcf MMBbls	Dec. 31, 2015
Disclosure of detailed information about property, plant and equipment [abstract]
Property acquisition costs | $	$ 0
Exploration costs for geological and geophysical studies | $	$ 8,828,809	$ 6,804,341
Estimated reserves percentage	97.00%
Remaining estimated reserve percentage	3.00%
Percenatge of developed and undeveloped reserves	11.00%
Developed and undeveloped reserves increase decrease	6,427	7,219
Percenatge of developed reserves	14.70%
Developed reserves increase decrease	4,166	4,866
Percentage of asset assigned developed and undeveloped reserves increase decrease	64.00%
Developed and undeveloped reserves added to offset	805.5
Percenatge of developed and undeveloped dry gas reserves	5.60%
Developed and undeveloped dry gas reserves increase decrease | Bcf	6,593	6,984
Percenatge of developed dry gas reserves	10.80%
Developed dry gas reserves increase decrease | Bcf	4,026	4,513
Percentage of asset assigned developed and undeveloped dry gas reserves increase decrease	64.00%
Developed and undeveloped dry gas reserves added to offset | Bcf	999
Percenatge of undeveloped dry gas reserves	3.90%
Undeveloped dry gas reserves increase decrease | Bcf	2,567	2,471
Exploratoroy activity in shallow waters and onshore regions incorporated	246
Increase of proved reserves	174.2
Reserve-replacement ratio	4.00%
Reserves production ratio of proved reserves, period		7 years 8 months 12 days
Proved reserves after net cash flows discount factor	10.00%	10.00%	10.00%

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Supplementary Information on Oil and Gas Exploration and Production Activities (Unaudited) - Summary of Results of Operations for Oil and Gas Producing Activities (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2017 MXN ($) $ / Boe $ / bbl $ / Mcf	Dec. 31, 2016 MXN ($) $ / Boe $ / bbl $ / Mcf	Dec. 31, 2015 MXN ($) $ / Boe $ / bbl $ / Mcf
Disclosure of detailed information about property, plant and equipment [line items]
Revenues from sale of oil and gas	$ 762,637,362	$ 616,380,608	$ 690,591,455
Hydrocarbon duties	375,156,405	304,299,019	376,682,705
Production costs (excluding taxes)	248,957,950	171,194,337	177,774,082
Other costs and expenses	(3,954,222)	61,359,271	20,360,540
Exploration expenses	14,993,433	39,693,273	31,244,564
Depreciation, depletion, amortization and accretion	240,672,906	(150,891,739)	527,014,056
Total production costs	875,826,472	425,654,161	1,133,075,947
Results of operations for oil and gas producing activities	$ (113,189,111)	$ 190,726,447	$ (442,484,491)
Oil Equivalent [member]
Disclosure of detailed information about property, plant and equipment [line items]
Average sales price | $ / Boe	38.63	29.18	37.17
Crude oil [member]
Disclosure of detailed information about property, plant and equipment [line items]
Average sales price | $ / bbl	48.71	36.55	48.22
Natural Gas [member]
Disclosure of detailed information about property, plant and equipment [line items]
Average sales price | $ / Mcf	4.32	3.01	3.78

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Supplementary Information on Oil and Gas Exploration and Production Activities (Unaudited) - Summary of Oil and Gas Proved Reserves (Detail)	12 Months Ended
	Dec. 31, 2017 Bcf MMBbls	Dec. 31, 2016 Bcf MMBbls	Dec. 31, 2015 Bcf MBbls
Crude oil reserve [member]
Proved developed and un-developed reserves:
Proved developed reserves	4,166	4,886	5,725
Proved undeveloped reserves	2,261	2,333	2,252
Total proved reserves | MMBbls	6,427
Dry gas reserve [member]
Proved developed and un-developed reserves:
Proved developed reserves	4,026	4,513	6,012
Proved undeveloped reserves	2,567	2,471	2,598
Total proved reserves	6,593

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Supplementary Information on Oil and Gas Exploration and Production Activities (Unaudited) - Disclosure of Proved Developed and Undeveloped Reserve (Detail)	12 Months Ended
	Dec. 31, 2017 Bcf MMBbls	Dec. 31, 2016 Bcf MMBbls	Dec. 31, 2015 Bcf MBbls
Crude oil reserve [member]
Proved developed and undeveloped reserves:
Beginning balance	7,219	7,977	10,292
Revisions	(95)	189	(1,491)
Extensions and discoveries	147	(55)	111
Production	(805)	(891)	(935)
Farm outs & transfer of fields due to NHC bidding process | MMBbls	(38)
Ending Balance	6,427	7,219	7,977
Proved developed reserves at December 31	4,166	4,886	5,725
Proved undeveloped reserves at December 31	2,261	2,333	2,252
Dry gas reserve [member]
Proved developed and undeveloped reserves:
Beginning balance	6,984	8,610	10,859
Revisions	169	(183)	(955)
Extensions and discoveries	468	(308)	47
Production	(999)	(1,134)	(1,341)
Farm outs & transfer of fields due to NHC bidding process	(29)
Ending Balance	6,593	6,984	8,610
Proved developed reserves at December 31	4,026	4,513	6,012
Proved undeveloped reserves at December 31	2,567	2,471	2,598

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Supplementary Information on Oil and Gas Exploration and Production Activities (Unaudited) - Disclosure of Standardized Measure of Discounted Future Net Cash Flows (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Future Net Cash Flows Relating To Proved Oil And Gas Reserves [Abstract]
Future cash inflows	$ 269,489	$ 228,196	$ 325,052
Future production costs (excluding profit taxes)	(114,369)	(87,942)	(99,948)
Future development costs	(26,229)	(25,515)	(32,560)
Future cash flows before tax	128,891	114,738	192,544
Future production and excess gains taxes	(129,377)	(108,960)	(167,056)
Future net cash flows	(487)	5,779	25,488
Effect of discounting net cash flows by 10%	(4,600)	(937)	(9,946)
Standardized measure of discounted future net cash flows	$ 4,113	$ 4,841	$ 15,541	$ 44,661

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Supplementary Information on Oil and Gas Exploration and Production Activities (Unaudited) - Disclosure of Standardized Measure of Discounted Future Net Cash Flows (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Future Net Cash Flows Relating To Proved Oil And Gas Reserves [Abstract]
Proved reserves after net cash flows discount factor	10.00%	10.00%	10.00%

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Supplementary Information on Oil and Gas Exploration and Production Activities (Unaudited) - Disclosure of Changes in standardized Measure of Discounted Future Net Cash Flows (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of Change in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Abstract]
Sales of oil and gas produced, net of production costs	$ (25,076)	$ (19,411)	$ (28,371)
Net changes in prices and production costs	26,355	(53,278)	(327,865)
Extensions and discoveries	3,639	1,105	3,086
Development cost incurred during the year	2,699	4,124	10,172
Changes in estimated development costs	2,744	1,763	(2,171)
Reserves revisions and timing changes	(1,353)	6,366	(22,801)
Accretion of discount of pre-tax net cash flows	5,891	11,094	43,394
Net changes in production and excess gains taxes	(15,628)	37,537	295,437
Aggregate change in standardized measure of discounted future net cash flows	(728)	(10,700)	(29,119)
As of January 1	4,841	15,541	44,661
As of December 31	4,113	4,841	15,541
Change	$ (728)	$ (10,700)	$ (29,119)