10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549 

______________________________

FORM 10-Q 

______________________________

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

For the quarterly period ended March 31, 2020

or 

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

For the transition period from  ________ to ________

Commission File Number: 1-13245

______________________________ 

PIONEER NATURAL RESOURCES COMPANY

(Exact name of Registrant as specified in its charter)

______________________________

Delaware	75-2702753
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

777 Hidden Ridge

Irving, Texas 75038

(Address of principal executive offices and zip code)

(972) 444-9001

(Registrant's telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol	Name of each exchange on which registered
Common Stock, par value $.01 per share	PXD	New York Stock Exchange

Not applicable

(Former name, former address and former fiscal year, if changed since last report) 

______________________________

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 every Interactive Data File required to be submitted 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 such files). 

Yes   ☒    No   ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.

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

If an emerging growth company, 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. ☐ 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes   ☐    No  ☒

Number of shares of Common Stock outstanding as of May 7, 2020     164,863,215

PIONEER NATURAL RESOURCES COMPANY

TABLE OF CONTENTS 

		Page
Cautionary Statement Concerning Forward-Looking Statements		3
Definitions of Certain Terms and Conventions Used Herein		4
PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements
	Consolidated Balance Sheets as of March 31, 2020 and December 31, 2019	6
	Consolidated Statements of Operations for the three months ended March 31, 2020 and 2019	8
	Consolidated Statements of Equity for the three months ended March 31, 2020 and 2019	9
	Consolidated Statements of Cash Flows for the three months ended March 31, 2020 and 2019	10
	Notes to Consolidated Financial Statements	11
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	29
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	40
Item 4.	Controls and Procedures	43
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	44
Item 1A.	Risk Factors	44
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	46
Item 6.	Exhibits	47
Signatures		48

2

PIONEER NATURAL RESOURCES COMPANY

Cautionary Statement Concerning Forward-Looking Statements

The information in this Quarterly Report on Form 10-Q (this "Report") contains forward-looking statements that involve risks and uncertainties. When used in this document, the words "believes," "plans," "expects," "anticipates," "forecasts," "intends," "continue," "may," "will," "could," "should," "future," "potential," "estimate" or the negative of such terms and similar expressions as they relate to Pioneer Natural Resources Company ("Pioneer" or the "Company") are intended to identify forward-looking statements, which are generally not historical in nature. The forward-looking statements are based on the Company's current expectations, assumptions, estimates and projections about the Company and the industry in which the Company operates. Although the Company believes that the expectations and assumptions reflected in the forward-looking statements are reasonable as and when made, they involve risks and uncertainties that are difficult to predict and, in many cases, beyond the Company's control.

These risks and uncertainties include, among other things, volatility of commodity prices, product supply and demand, the impact of a widespread outbreak of an illness, such as the COVID-19 pandemic, on global and U.S. economic activity, competition, the ability to obtain environmental and other permits and the timing thereof, other government regulation or action, the ability to obtain approvals from third parties and negotiate agreements with third parties on mutually acceptable terms, litigation, the costs and results of drilling and operations, availability of equipment, services, resources and personnel required to perform the Company's drilling and operating activities, access to and availability of transportation, processing, fractionation, refining, storage and export facilities, Pioneer's ability to replace reserves, implement its business plans or complete its development activities as scheduled, access to and cost of capital, the financial strength of counterparties to Pioneer's credit facilities, investment instruments and derivative contracts and purchasers of Pioneer's oil, NGL and gas production, uncertainties about estimates of reserves, identification of drilling locations and the ability to add proved reserves in the future, the assumptions underlying production forecasts, quality of technical data, environmental and weather risks, including the possible impacts of climate change, cybersecurity risks, ability to implement planned stock repurchases, the risks associated with the ownership and operation of the Company's oilfield services businesses and acts of war or terrorism. These and other risks are described in the Company's Annual Report on Form 10-K, this and other Quarterly Reports on Form 10-Q and other filings with the United States Securities and Exchange Commission. In addition, the Company may be subject to currently unforeseen risks that may have a materially adverse effect on it. Accordingly, no assurances can be given that the actual events and results will not be materially different than the anticipated results described in the forward-looking statements. See "Part I, Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations," "Part 1, Item 3. Quantitative and Qualitative Disclosures About Market Risk" and "Part II, Item 1A. Risk Factors" in this Report and "Part I, Item 1. Business — Competition, Markets and Regulations," "Part I, Item 1A. Risk Factors," "Part II, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" and "Part II, Item 7A. Quantitative and Qualitative Disclosures About Market Risk" in the Company's Annual Report on Form 10-K for the year ended December 31, 2019 for a description of various factors that could materially affect the ability of Pioneer to achieve the anticipated results described in the forward-looking statements. Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date hereof. The Company undertakes no duty to publicly update these statements except as required by law.

3

PIONEER NATURAL RESOURCES COMPANY

Definitions of Certain Terms and Conventions Used Herein

Within this Report, the following terms and conventions have specific meanings:

•"Bbl" means a standard barrel containing 42 United States gallons.

•"Bcf" means one billion cubic feet and is a measure of gas volume.

•"BOE" means a barrel of oil equivalent and is a standard convention used to express oil and gas volumes on a comparable oil equivalent basis. Gas equivalents are determined under the relative energy content method by using the ratio of six thousand cubic feet of gas to one Bbl of oil or natural gas liquid.

•"BOEPD" means BOE per day.

•"Brent" means Brent oil price, a major trading classification of light sweet oil that serves as a benchmark price for oil worldwide.

•"Btu" means British thermal unit, which is a measure of the amount of energy required to raise the temperature of one pound of water one degree Fahrenheit.

•"DD&A" means depletion, depreciation and amortization.

•"GAAP" means accounting principles generally accepted in the United States of America.

•"HH" means Henry Hub, a distribution hub in Louisiana that serves as the delivery location for gas futures contracts on the NYMEX.

•"MBbl" means one thousand Bbls.

•"MBOE" means one thousand BOEs.

•"Mcf" means one thousand cubic feet and is a measure of gas volume.

•"MMBtu" means one million Btus.

•"Mont Belvieu" means the daily average natural gas liquids components as priced in OPIS in the table "U.S. and Canada LP – Gas Weekly Averages" at Mont Belvieu, Texas.

•"NGLs" means natural gas liquids, which are the heavier hydrocarbon liquids that are separated from the gas stream; such liquids include ethane, propane, isobutane, normal butane and natural gasoline.

•"NYMEX" means the New York Mercantile Exchange.

•"OPEC" means the Organization of Petroleum Exporting Countries.

•"Pioneer" or the "Company" means Pioneer Natural Resources Company and its subsidiaries.

•"Proved reserves" mean those quantities of oil and gas, which, by analysis of geosciences 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.

(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 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.

•"SEC" means the United States Securities and Exchange Commission.

•"U.S." means United States.

•"WTI" means West Texas Intermediate, a light sweet blend of oil produced from fields in western Texas and is a grade of oil used as a benchmark in oil pricing.

•With respect to information on the working interest in wells, drilling locations and acreage, "net" wells, drilling locations and acres are determined by multiplying "gross" wells, drilling locations and acres by the Company's working interest in such wells, drilling locations or acres. Unless otherwise specified, wells, drilling locations and acreage statistics quoted herein represent gross wells, drilling locations or acres.

•All currency amounts are expressed in U.S. dollars.

5

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

PIONEER NATURAL RESOURCES COMPANY

CONSOLIDATED BALANCE SHEETS

(in millions)

	March 31, 2020		December 31, 2019
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	784	$	631
Restricted cash	74		74
Accounts receivable:
Trade, net	555		1,032
Due from affiliates	—		3
Income taxes receivable	9		7
Inventories	188		205
Derivatives	386		32
Investment in affiliate	42		187
Other	31		20
Total current assets	2,069		2,191
Oil and gas properties, using the successful efforts method of accounting:
Proved properties	23,029		22,444
Unproved properties	583		584
Accumulated depletion, depreciation and amortization	(8,987)		(8,583)
Total oil and gas properties, net	14,625		14,445
Other property and equipment, net	1,629		1,632
Operating lease right-of-use assets	250		280
Goodwill	261		261
Derivatives	43		—
Other assets	174		258
	$	19,051	$	19,067

The financial information included as of March 31, 2020 has been prepared by management

without audit by independent registered public accountants.

The accompanying notes are an integral part of these consolidated financial statements.

6

PIONEER NATURAL RESOURCES COMPANY

CONSOLIDATED BALANCE SHEETS (continued)

(in millions, except share data) 

	March 31, 2020		December 31, 2019
	(Unaudited)
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable:
Trade	$	973	$	1,221
Due to affiliates	100		190
Interest payable	18		53
Income taxes payable	3		3
Current portion of long-term debt	499		450
Derivatives	3		12
Operating leases	128		136
Other	356		431
Total current liabilities	2,080		2,496
Long-term debt	2,140		1,839
Derivatives	3		8
Deferred income taxes	1,465		1,389
Operating leases	146		170
Other liabilities	1,006		1,046
Equity:
Common stock, $0.01 par value; 500,000,000 shares authorized; 175,373,639 and 175,057,889 shares issued as of March 31, 2020 and December 31, 2019, respectively	2		2
Additional paid-in capital	9,176		9,161
Treasury stock at cost: 10,510,424 and 9,511,248 shares as of March 31, 2020 and December 31, 2019, respectively	(1,190)		(1,069)
Retained earnings	4,223		4,025
Total equity	12,211		12,119
Commitments and contingencies
	$	19,051	$	19,067

The financial information included as of March 31, 2020 has been prepared by management

without audit by independent registered public accountants.

The accompanying notes are an integral part of these consolidated financial statements.

7

PIONEER NATURAL RESOURCES COMPANY

CONSOLIDATED STATEMENTS OF OPERATIONS

(in millions, except per share data)

(Unaudited) 

	Three Months Ended March 31,
	2020		2019
Revenues and other income:
Oil and gas	$	1,095	$	1,135
Sales of purchased oil and gas	915		1,109
Interest and other income (loss), net	(206)		191
Derivative gain (loss), net	453		(13)
Loss on disposition of assets, net	—		(9)
	2,257		2,413
Costs and expenses:
Oil and gas production	176		221
Production and ad valorem taxes	75		68
Depletion, depreciation and amortization	434		421
Purchased oil and gas	1,028		957
Exploration and abandonments	9		20
General and administrative	56		94
Accretion of discount on asset retirement obligations	2		3
Interest	27		29
Other	85		147
	1,892		1,960
Income before income taxes	365		453
Income tax provision	(76)		(103)
Net income attributable to common stockholders	$	289	$	350
Basic and diluted net income per share attributable to common stockholders	$	1.74	$	2.06
Basic and diluted weighted average shares outstanding	166		169
Dividends declared per share	$	0.55	$	0.32

The financial information included herein has been prepared by management

without audit by independent registered public accountants.

The accompanying notes are an integral part of these consolidated financial statements.

8

PIONEER NATURAL RESOURCES COMPANY

CONSOLIDATED STATEMENTS OF EQUITY

(in millions, except share data and dividends per share)

(Unaudited)

		Equity Attributable To Common Stockholders
	Shares Outstanding	Common Stock		Additional Paid-in Capital		Treasury Stock		Retained Earnings		Total Equity
	(in thousands)
Balance as of December 31, 2019	165,547	$	2	$	9,161	$	(1,069)	$	4,025	$	12,119
Dividends declared ($0.55 per share)	—	—		—		—		(91)		(91)
Exercise of long-term incentive stock options	8	—		(1)		1		—		—
Purchases of treasury stock	(1,007)	—		—		(122)		—		(122)
Stock-based compensation costs:
Issued awards	316	—		—		—		—		—
Compensation costs included in net income	—	—		16		—		—		16
Net income	—	—		—		—		289		289
Balance as of March 31, 2020	164,864	$	2	$	9,176	$	(1,190)	$	4,223	$	12,211

		Equity Attributable To Common Stockholders
	Shares Outstanding	Common Stock		Additional Paid-in Capital		Treasury Stock		Retained Earnings		Total Equity
	(in thousands)
Balance as of December 31, 2018	169,499	$	2	$	9,062	$	(423)	$	3,470	$	12,111
Dividends declared ($0.32 per share)	—	—		—		—		(54)		(54)
Exercise of long-term incentive stock options	10	—		(1)		1		—		—
Purchases of treasury stock	(1,594)	—		—		(222)		—		(222)
Stock-based compensation costs:
Issued awards	507	—		—		—		—		—
Compensation costs included in net income	—	—		24		—		—		24
Net income	—	—		—		—		350		350
Balance as of March 31, 2019	168,422	$	2	$	9,085	$	(644)	$	3,766	$	12,209

The financial information included herein has been prepared by management

without audit by independent registered public accountants.

The accompanying notes are an integral part of these consolidated financial statements.

9

PIONEER NATURAL RESOURCES COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in millions)

(Unaudited)

	Three Months Ended March 31,
	2020		2019
Cash flows from operating activities:
Net income	$	289	$	350
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion, depreciation and amortization	434		421
Impairment of inventory and other property and equipment	—		32
Exploration expenses, including dry holes	2		1
Deferred income taxes	76		103
Loss on disposition of assets, net	—		9
Accretion of discount on asset retirement obligations	2		3
Interest expense	5		1
Derivative related activity	(412)		17
Amortization of stock-based compensation	16		24
Investment in affiliate valuation adjustment	145		(174)
South Texas contingent consideration valuation adjustment	63		—
South Texas deficiency fee obligation	69		—
Other	31		62
Change in operating assets and liabilities:
Accounts receivable	479		(69)
Inventories	16		(36)
Other assets	21		(15)
Accounts payable	(284)		(74)
Interest payable	(35)		(29)
Other liabilities	(92)		(22)
Net cash provided by operating activities	825		604
Cash flows from investing activities:
Proceeds from disposition of assets, net of cash sold	1		6
Proceeds from investments	—		112
Additions to oil and gas properties	(639)		(741)
Additions to other assets and other property and equipment	(43)		(72)
Net cash used in investing activities	(681)		(695)
Cash flows from financing activities:
Borrowing under credit facility	800		—
Principal payments on long-term debt	(450)		—
Payments of other liabilities	(146)		(1)
Purchases of treasury stock	(122)		(222)
Dividends paid	(73)		—
Net cash provided by (used in) financing activities	9		(223)
Net increase (decrease) in cash, cash equivalents and restricted cash	153		(314)
Cash, cash equivalents and restricted cash, beginning of period	705		825
Cash, cash equivalents and restricted cash, end of period	$	858	$	511

The financial information included herein has been prepared by management

without audit by independent registered public accountants.

The accompanying notes are an integral part of these consolidated financial statements.

10

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

NOTE 1. Organization and Nature of Operations

Pioneer Natural Resources Company ("Pioneer" or the "Company") is a Delaware corporation whose common stock is listed and traded on the New York Stock Exchange. The Company is a large independent oil and gas exploration and production company that explores for, develops and produces oil, natural gas liquids ("NGLs") and gas in the Permian Basin in West Texas.

NOTE 2. Basis of Presentation

Presentation. In the opinion of management, the unaudited interim consolidated financial statements of the Company as of March 31, 2020 and for the three months ended March 31, 2020 and 2019 include all adjustments and accruals, consisting only of normal, recurring adjustments and accruals necessary for a fair presentation of the results for the interim periods in conformity with generally accepted accounting principles in the United States ("GAAP"). The operating results for the three months ended March 31, 2020 are not necessarily indicative of results for a full year.

Certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted in accordance with the rules and regulations of the United States Securities and Exchange Commission (the "SEC"). These unaudited interim consolidated financial statements should be read together with the consolidated financial statements and notes thereto included in the Company's Annual Report on Form 10-K for the year ended December 31, 2019.

Use of estimates in the preparation of financial statements. Preparation of the Company's unaudited interim consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Depletion of oil and gas properties and evaluations for impairment of goodwill and proved and unproved oil and gas properties, in part, is determined using estimates of proved, probable and possible oil and gas reserves. There are numerous uncertainties inherent in the estimation of quantities of proved, probable and possible reserves and in the projection of future rates of production and the timing of development expenditures. Similarly, evaluations for impairment of proved and unproved oil and gas properties are subject to numerous uncertainties including, among others, estimates of future recoverable reserves and commodity price outlooks. Actual results could differ from the estimates and assumptions utilized.

Impact of the COVID-19 Pandemic. A novel strain of the coronavirus ("COVID-19") surfaced in late 2019 and has spread around the world, including to the United States. In March 2020, the World Health Organization declared COVID-19 a pandemic, and the President of the United States declared the COVID-19 outbreak a national emergency. The COVID-19 pandemic has significantly affected the global economy, disrupted global supply chains and created significant volatility in the financial markets. In addition, the COVID-19 pandemic has resulted in travel restrictions, business closures and other restrictions that have disrupted the demand for oil throughout the world and when combined with the oil supply increase attributable to the battle for market share among OPEC, Russia and other oil producing nations, resulted in oil prices declining significantly beginning late February 2020. The length of this demand disruption is unknown, and there is significant uncertainty regarding the long-term impact to global oil demand, which is negatively impacting the Company's results of operations and planned 2020 capital activities.

Adoption of new accounting standards. In June 2016, the FASB issued ASU 2016-13, "Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments" ("ASU 2016-13"). Effective January 1, 2020, the Company adopted ASU 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments prospectively. This ASU replaces the incurred loss impairment model with an expected credit loss impairment model for financial instruments, including trade receivables. The amendment requires entities to consider forward-looking information to estimate expected credit losses, resulting in earlier recognition of losses for receivables that are current or not yet due, which were not considered under the previous accounting guidance. The impact of the adoption of this ASU was not material.

The Company is exposed to credit losses primarily through sales of oil, NGLs, gas and purchased oil and gas. The Company’s expected loss allowance methodology for accounts receivable is developed using historical collection experience, current and future economic and market conditions and a review of the current status of customers' trade accounts receivables.

11

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

Due to the short-term nature of such receivables, the estimate of amount of accounts receivable that may not be collected is based on aging of the accounts receivable balances and the financial condition of customers. The Company’s monitoring activities include timely account reconciliation, dispute resolution, payment confirmation, consideration of customers' financial condition and macroeconomic conditions. Balances are written off when determined to be uncollectible. The Company considered the current and expected future economic and market conditions surrounding the COVID-19 pandemic and determined that the estimate of credit losses was not significantly impacted.

NOTE 3. Divestitures, Decommissioning and Restructuring Activities

Divestitures

In May 2019, the Company completed the sale of its Eagle Ford assets and other remaining assets in South Texas (the "South Texas Divestiture") to an unaffiliated third party in exchange for total consideration having an estimated fair value of $210 million, after normal closing adjustments. The fair value of the consideration included (i) net cash proceeds of $2 million, (ii) $136 million in contingent consideration and (iii) a $72 million receivable associated with estimated deficiency fees to be paid by the buyer.

Contingent Consideration. Per the terms of the purchase and sale agreement, the Company is entitled to receive contingent consideration of up to $450 million based on future annual oil and NGL prices during each of the five years from 2020 to 2024. The Company determined the fair value of the contingent consideration as of the date of the sale to be $136 million using an option pricing model. The fair value of the contingent consideration is included in noncurrent other assets in the consolidated balance sheets since, if earned, such consideration will be paid by the buyer in installments beginning in 2023 through 2025. The Company revalues the contingent consideration each reporting period and records the resulting valuation changes in net interest and other income (loss) in the consolidated statements of operations. The Company recorded a loss on valuation adjustment of $63 million for the three months ended March 31, 2020. The fair value of the contingent consideration was $28 million as of March 31, 2020. See Note 4, Note 5 and Note 13 for additional information.

Deficiency Fee Obligation. The Company transferred its long-term midstream agreements and associated minimum volume commitments ("MVC") to the buyer. However, the Company retained the obligation to pay 100 percent of any deficiency fees associated with the MVC from January 2019 through July 2022. The Company determined the fair value of the deficiency fee obligation as of the date of the sale to be $348 million using a probability weighted present value model. The deficiency fee obligation is included in current or noncurrent liabilities in the consolidated balance sheets, based on the timing of payments. In March 2020, the Company recorded a charge of $69 million in other expense for the three months ended March 31, 2020, due to changes in the Company's forecasted deficiency fee payments. The estimated remaining deficiency fee obligation was $323 million as of March 31, 2020. See Note 4, Note 10 and Note 14 for additional information.

Deficiency Fee Receivable. The buyer is required to reimburse the Company for 18 percent of the deficiency fees paid under the transferred midstream agreements from January 2019 through July 2022. Such reimbursement will be paid by the buyer in installments beginning in 2023 through 2025. The Company determined the fair value of the deficiency fee receivable as of the date of the sale to be $72 million using a credit risk-adjusted valuation model. The deficiency fee receivable is included in noncurrent other assets in the consolidated balance sheets. See Note 4 for additional information.

Restricted Cash. As of March 31, 2020, the Company has $74 million deposited in an escrow account to be used to fund future deficiency fee payments. The escrow account balance is included in restricted cash in the consolidated balance sheet as of March 31, 2020. Beginning in 2021, the required escrow balance will decline to $50 million and, to the extent that there is any remaining balance after the payment of deficiency fees, the balance will become unrestricted and revert to the Company on March 31, 2023.

Decommissioning

In November 2018, the Company announced plans to close its sand mine located in Brady, Texas and transition its proppant supply requirements to West Texas sand sources. During the three months ended March 31, 2019, the Company recorded $23 million of accelerated depreciation and $13 million of inventory and other property and equipment impairment charges associated with the sand mine closure. See Note 14 for additional information.

12

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

Restructuring

During 2019, the Company implemented a corporate restructuring program to align its cost structure with the needs of a Permian Basin-focused company. The restructuring occurred in three phases (collectively, the "Corporate Restructuring Program") as follows:

•In March 2019, the Company made certain changes to its leadership and organizational structure, which included the early retirement and departure of certain officers of the Company,

•In April 2019, the Company adopted a voluntary separation program ("VSP") for certain eligible employees, and

•In May 2019, the Company implemented an involuntary separation program ("ISP").

The employee-related costs associated with the restructuring were primarily recorded in other expense in the consolidated statements of operations. Obligations associated with employee-related charges are included in accounts payable - due to affiliates in the consolidated balance sheets. See Note 14 for additional information.

The changes in the Company's total employee-related obligations are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Beginning employee-related obligations	$	6	$	27
Additions (Note 14)	—		13
Cash payments	(5)		(10)
Noncash changes	—		(4)
Ending employee-related obligations	$	1	$	26

NOTE 4. Fair Value Measurements

The Company determines fair value based on the price that would be received from selling an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are based upon inputs that market participants use in pricing an asset or liability, which are characterized according to a hierarchy that prioritizes those inputs based on the degree to which they are observable. Observable inputs represent market data obtained from independent sources, whereas unobservable inputs reflect a company's own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. The fair value input hierarchy level to which an asset or liability measurement in its entirety falls is determined based on the lowest level input that is significant to the measurement in its entirety.

The three input levels of the fair value hierarchy are as follows:

•Level 1 – quoted prices for identical assets or liabilities in active markets.

•Level 2 – quoted prices for similar assets or liabilities in active markets; quoted prices for identical or similar assets or liabilities in markets that are not active; inputs other than quoted prices that are observable for the asset or liability (e.g. interest rates) and inputs derived principally from or corroborated by observable market data by correlation or other means.

•Level 3 – unobservable inputs for the asset or liability, typically reflecting management's estimate of assumptions that market participants would use in pricing the asset or liability. The fair values are therefore, determined using model-based techniques, including discounted cash flow models.

13

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

Assets and liabilities measured at fair value on a recurring basis. Assets and liabilities measured at fair value on a recurring basis are as follows:

	As of March 31, 2020
	Fair Value Measurement
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(in millions)
Assets:
Commodity price derivatives	$	—	$	429	$	—	$	429
Deferred compensation plan assets	64		—		—		64
Investment in affiliate	42		—		—		42
Contingent consideration	—		28		—		28
Total assets	106		457		—		563
Liabilities:
Commodity price derivatives	—		6		—		6
	$	106	$	451	$	—	$	557

	As of December 31, 2019
	Fair Value Measurement
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(in millions)
Assets:
Commodity price derivatives	$	—	$	32	$	—	$	32
Deferred compensation plan assets	85		—		—		85
Investment in affiliate	187		—		—		187
Contingent consideration	—		91		—		91
Total assets	272		123		—		395
Liabilities:
Commodity price derivatives	—		20		—		20
	$	272	$	103	$	—	$	375

Commodity price derivatives. The Company's commodity price derivatives represent oil, NGL and gas swap contracts, collar contracts, collar contracts with short puts and basis swap contracts. The asset and liability measurements for the Company's commodity price derivative contracts are determined using Level 2 inputs. The Company utilizes discounted cash flow and option-pricing models for valuing its commodity price derivatives.

The asset and liability values attributable to the Company's commodity price derivatives were determined based on inputs that include (i) the contracted notional volumes, (ii) independent active market price quotes, (iii) the applicable estimated

14

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

credit-adjusted risk-free rate yield curve and (iv) the implied rate of volatility inherent in the collar contracts and collar contracts with short puts, which is based on active and independent market-quoted volatility factors.

Deferred compensation plan assets. The Company's deferred compensation plan assets include investments in equity and mutual fund securities that are actively traded on major exchanges. The fair value of these investments is determined using Level 1 inputs based on observable prices on major exchanges.

Investment in affiliate. The Company elected the fair value option for measuring its equity method investment in ProPetro Holding Corp. ("ProPetro"). The fair value of its investment in ProPetro is determined using Level 1 inputs based on observable prices on a major exchange. See Note 11 and Note 13 for additional information.

Contingent consideration. The Company has a right to receive contingent consideration in conjunction with the South Texas Divestiture of up to $450 million based on future oil and NGL prices during each of the five years from 2020 to 2024. The fair value of the contingent consideration is determined using Level 2 inputs based on an option pricing model using quoted future commodity prices based on active markets, implied volatility factors and counterparty credit risk assessments. See Note 3, Note 5 and Note 13 for additional information. 

Assets and liabilities measured at fair value on a nonrecurring basis. Certain assets and liabilities are measured at fair value on a nonrecurring basis. These assets and liabilities are not measured at fair value on an ongoing basis, but are subject to fair value adjustments in certain circumstances. These assets and liabilities can include inventory, proved and unproved oil and gas properties, goodwill and other long-lived assets that are written down to fair value when they are impaired or held for sale.

Other assets. During the three months ended March 31, 2019, the Company impaired $13 million of inventory and other property and equipment related to the decommissioning of the Company's Brady, Texas sand mine, as these assets had no remaining future economic value. In addition, the Company recognized a $15 million impairment charge related to pressure pumping assets that were excluded from the December 2018 sale of the Company's pumping services assets. See Note 14 for additional information.

South Texas Divestiture. The Company recorded a deficiency fee obligation and related deficiency fee receivable in conjunction with the 2019 South Texas Divestiture. The fair value of the deficiency fee obligation and deficiency fee receivable was determined using Level 3 inputs based on a probability-weighted forecast that considers historical results, market conditions and various development plans to arrive at the estimated present value of the deficiency payments and corresponding receipts. The change to the Company's forecasted deficiency fee obligation, as a result of the expected impact of the COVID-19 pandemic on the ability of the buyer to satisfy the MVC, resulted in the Company recording a charge of $69 million to other expense for the three months ended March 31, 2020. The present value of the future cash payments and expected cash receipts were determined using a 3.6 percent and 3.2 percent discount rate, respectively, based on the estimated timing of future payments and receipts and the Company's counterparty credit risk assessments. See Note 3, Note 10 and Note 14 for additional information.

Impact of the COVID-19 pandemic on certain assets and liabilities measured at fair value on a nonrecurring basis.

Proved Properties. The Company performs assessments of its proved oil and gas properties accounted for under the successful efforts method of accounting, whenever events or circumstances indicate that the carrying value of those assets may not be recoverable. An impairment loss is indicated if the sum of the expected future cash flows, including from vertical integrated services that are used in the development of the assets, is less than the carrying amount of the assets, including the carrying value of the vertical integrated services and operating lease right-of-use assets. In these circumstances, the Company recognizes an impairment charge for the amount by which the carrying amount of the assets exceeds the estimated fair value of the assets.

Due to the decrease in management's commodity price outlooks during the first quarter of 2020, which represent longer-term outlooks that are developed based on third party longer term commodity price estimates as of a measurement date ("Management's Price Outlooks"), the Company performed an impairment assessment of its proved oil and gas properties as of March 31, 2020 and determined that its proved oil and gas properties were not impaired. The primary factors that may affect estimates of future cash flows for the Company's proved oil and gas properties are (i) future reserve adjustments, both positive and negative, to proved reserves and appropriate risk-adjusted probable and possible reserves, (ii) results of future drilling activities, (iii) Management's Price Outlooks and (iv) increases or decreases in production and capital costs. The average oil price per barrel and gas price per thousand cubic feet utilized in the respective Management's Price Outlooks are as follows:

15

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

	As of March 31, 2020
	Oil		Gas
Management's Price Outlooks	$	42.84	$	2.49

Goodwill. Goodwill is assessed for impairment whenever it is likely that events or circumstances indicate the carrying value of a reporting unit exceeds its fair value, but no less often than annually. An impairment charge is recorded for the amount by which the carrying amount exceeds the fair value of a reporting unit in the period it is determined to be impaired.

During the three months ended March 31, 2020 the Company's market capitalization decreased from $25 billion at December 31, 2019 to $12 billion at March 31, 2020. The Company determined that the significant decline in its market capitalization during the first quarter of 2020 indicated that an impairment loss on the Company's $261 million carrying amount of goodwill may have been incurred. Based on the Company's assessment of the fair value of goodwill as of March 31, 2020, the Company determined that its goodwill was not impaired. The fair value of the Company's reporting unit, as of March 31, 2020, was $15.5 billion, calculated as the Company's market capitalization plus a control premium, which is 27 percent in excess of the March 31, 2020 carrying value of the Company's reporting unit. A further decline in the Company’s share price for a sustained period of time, or a significant decrease in the future cash flows from the Company's proved oil and gas reserves, among other factors, could significantly impact the impairment analysis and may result in future goodwill impairment charges.

There is significant uncertainty surrounding the long-term impact to global oil demand due to the effects of the COVID-19 pandemic, coupled with significant excess oil supply that is rapidly filling worldwide storage. These conditions are negatively impacting the Company's 2020 forecasted capital activities and production levels. It is reasonably possible that the carrying value of the Company's proved oil and gas properties or goodwill could exceed their estimated fair value resulting in the need to impair their carrying values in the future. If incurred, an impairment of the Company's proved oil and gas properties or goodwill could have a material adverse effect on the Company's financial condition and results of operation.

Financial instruments not carried at fair value. Carrying values and fair values of financial instruments that are not carried at fair value in the consolidated balance sheets are as follows:

	As of March 31, 2020				As of December 31, 2019
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(in millions)
Assets:
Cash and cash equivalents:
Cash (a)	$	784	$	784	$	631	$	631
Restricted cash (a)	$	74	$	74	$	74	$	74
Liabilities:
Current portion of long-term debt:
Senior notes (b)	$	499	$	500	$	450	$	451
Long-term debt:
Credit facility (c)	$	796	$	797	$	—	$	—
Senior notes (b)	1,344		1,397		1,839		1,995
Total	$	2,140	$	2,194	$	1,839	$	1,995

______________________

(a)Fair value approximates carrying value due to the short-term nature of the instruments.

(b)Fair value is determined using Level 2 inputs. The Company's senior notes are quoted, but not actively traded on major exchanges; therefore, fair value is based on periodic values as quoted on major exchanges.

(c)Fair value is determined using Level 2 inputs.

The Company has other financial instruments consisting primarily of receivables, payables, other current assets and liabilities that approximate fair value due to the nature of the instrument and their relatively short maturities. Non-financial assets and liabilities initially measured at fair value include assets acquired and liabilities assumed in a business combination, goodwill and asset retirement obligations.

16

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

NOTE 5. Derivative Financial Instruments

The Company primarily utilizes commodity swap contracts, collar contracts, collar contracts with short puts and basis swap contracts to (i) reduce the effect of price volatility on the commodities the Company produces and sells or consumes, (ii) support the Company's annual capital budgeting and expenditure plans and (iii) reduce commodity price risk associated with certain capital projects. The Company also, from time to time, utilizes interest rate contracts to reduce the effect of interest rate volatility on the Company's indebtedness.

Oil production derivatives. The Company sells its oil production at the lease and the sales contracts governing such oil production are tied directly to, or are highly correlated with, New York Mercantile Exchange ("NYMEX") West Texas Intermediate ("WTI") oil prices. The Company also enters into pipeline capacity commitments in order to secure available oil, NGL and gas transportation capacity from its areas of production. To diversify the oil prices it receives, the Company enters into third party purchase transactions in its area of production and separate third party transactions for the sales of such purchased oil to Gulf Coast refineries or international export markets at prices that are highly correlated to Brent oil prices. As a result, the Company will generally use Brent derivative contracts to manage future oil price volatility.

17

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

Volumes per day associated with the Company's outstanding oil derivative contracts as of March 31, 2020 and the weighted average oil prices for those contracts are as follows:

	2020						Year Ending December 31, 2021
	Second Quarter		Third Quarter		Fourth Quarter
Brent collar contracts with short puts: (a)
Volume per day (Bbl)	135,500		115,500		115,500		—
Price per Bbl:
Ceiling	$	68.84	$	69.78	$	69.78	$	—
Floor	$	61.76	$	62.06	$	62.06	$	—
Short put	$	53.48	$	53.56	$	53.56	$	—
Brent swap contracts:
Volume per day (Bbl)	98,911		177,900		160,900		57,750
Price per Bbl	$	37.27	35.68		$	36.43	$	43.29
Brent call contracts sold:
Volume per day (Bbl) (b)	—		—		—		20,000
Price per Bbl	$	—	$	—	$	—	$	69.74
Brent collar contracts with short puts:
Volume per day (Bbl)	120,000		30,000		30,000		96,000
Price per Bbl:
Ceiling	$	36.53	$	43.09	$	43.09	$	47.07
Floor	$	31.08	$	34.83	$	34.83	$	42.50
Short put	$	21.28	$	24.83	$	24.83	$	31.45

______________________

(a)Represents collar contracts with short puts that were entered into prior to March 2020. During March 2020, the Company entered into incremental swap contracts and collar contracts with short puts to provide additional downside price protection for the second quarter through fourth quarter 2020 volumes.

(b)The referenced call contracts were sold in exchange for higher ceiling prices on certain 2020 collar contracts with short puts.

See Note 17 for changes in the Company's derivative contracts subsequent to March 31, 2020.

NGL production derivatives. All material physical sales contracts governing the Company's NGL production are tied directly or indirectly to Mont Belvieu, Texas NGL component product prices. The Company uses derivative contracts to manage the volatility of NGL component product prices. As of March 31, 2020, the Company did not have any NGL derivative contracts outstanding.

Gas production derivatives. All material physical sales contracts governing the Company's gas production are tied directly or indirectly to NYMEX Henry Hub ("HH") gas prices or regional index prices where the gas is sold. The Company uses derivative contracts to manage gas price volatility and basis swap contracts to reduce basis risk between HH prices and actual index prices at which the gas is sold.

18

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

Volumes per day associated with outstanding gas derivative contracts as of March 31, 2020 and the weighted average gas prices for those contracts are as follows: 

	2020						Year Ending December 31, 2021
	Second Quarter		Third Quarter		Fourth Quarter
Swap contracts:
Volume per day (MMBtu)	30,000		30,000		16,739		2,466
Price per MMBtu	$	2.41	$	2.41	$	2.43	$	2.46
Basis swap contracts:
Permian Basin index swap volume per day(MMBtu) (a)	30,000		30,000		16,739		2,466
Price differential ($/MMBtu)	$	(1.68)	$	(1.68)	$	(1.59)	$	(1.46)

______________________

(a)The referenced basis swap contracts fix the basis differentials between the index price at which the Company sells its Permian Basin gas and the NYMEX index prices used in swap contracts.

Contingent consideration. The Company's right to receive contingent consideration in conjunction with the South Texas Divestiture was determined to be a derivative financial instrument that is not designated as a hedging instrument. The contingent consideration of up to $450 million is based on oil and NGL prices during each of the five years from 2020 to 2024. See Note 3 and Note 4 for additional information.

Derivative accounting. The Company's derivatives are accounted for as non-hedge derivatives and therefore all changes in the fair values of its derivative contracts are recognized as gains or losses in the earnings of the periods in which they occur. The Company enters into commodity price derivatives under master netting arrangements, which, in an event of default, allows the Company to offset payables to and receivables from the defaulting counterparty.

Noncash gains and losses associated with the Company's commodity price derivatives and contingent consideration are separately presented in operating activities within the consolidated statements of cash flows.

19

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

Fair value. The fair value of derivative financial instruments not designated as hedging instruments is as follows:

As of March 31, 2020
Type	Consolidated Balance Sheet Location	Fair Value		Gross Amounts Offset in the Consolidated Balance Sheet		Net Fair Value Presented in the Consolidated Balance Sheet
		(in millions)
Assets:
Commodity price derivatives	Derivatives - current	$	386	$	—	$	386
Commodity price derivatives	Derivatives - noncurrent	$	43	$	—	$	43
Contingent consideration	Other assets - noncurrent	$	28	$	—	$	28
Liabilities:
Commodity price derivatives	Derivatives - current	$	3	$	—	$	3
Commodity price derivatives	Derivatives - noncurrent	$	3	$	—	$	3

As of December 31, 2019
Type	Consolidated Balance Sheet Location	Fair Value		Gross Amounts Offset in the Consolidated Balance Sheet		Net Fair Value Presented in the Consolidated Balance Sheet
		(in millions)
Assets:
Commodity price derivatives	Derivatives - current	$	32	$	—	$	32
Contingent consideration	Other assets - noncurrent	$	91	$	—	$	91
Liabilities:
Commodity price derivatives	Derivatives - current	$	12	$	—	$	12
Commodity price derivatives	Derivatives - noncurrent	$	8	$	—	$	8

Gains and losses on derivative contracts are as follows:

Derivatives Not Designated  as Hedging Instruments	Location of Gain (Loss) Recognized in Earnings on Derivatives	Three Months Ended March 31,
		2020		2019
		(in millions)
Commodity price derivatives	Derivative gain (loss), net	$	475	$	(13)
Contingent consideration	Interest and other income (loss), net	$	(63)	$	—
Interest rate derivatives	Derivative gain (loss), net	$	(22)	$	—

The Company uses credit and other financial criteria to evaluate the credit standing of, and to select, counterparties to its derivative instruments. Although the Company does not obtain collateral or otherwise secure the fair value of its derivative instruments, associated credit risk is mitigated by the Company's credit risk policies and procedures.

NOTE 6. Exploratory Costs

The Company capitalizes exploratory well and project costs until a determination is made that the well or project has either found proved reserves, is impaired or is sold. The Company's capitalized exploratory well and project costs are included in proved properties in the consolidated balance sheets. If the exploratory well or project is determined to be impaired, the impaired costs are charged to exploration and abandonments expense.

20

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

The changes in capitalized exploratory well costs are as follows:

	Three Months Ended March 31, 2020
	(in millions)
Beginning capitalized exploratory well costs	$	660
Additions to exploratory well costs pending the determination of proved reserves	526
Reclassification due to determination of proved reserves	(577)
Ending capitalized exploratory well costs	$	609

The Company has no wells or projects with exploratory well costs that have been suspended for a period of greater than one year.

NOTE 7. Long-term Debt

Credit facility. The Company's long-term debt consists of senior notes, a revolving corporate credit facility (the "Credit Facility") and the effects of issuance costs and discounts. The Credit Facility is maintained with a syndicate of financial institutions and has aggregate loan commitments of $1.5 billion. The Credit Facility has a maturity date in October 2023. As of March 31, 2020, the Company had $800 million of outstanding borrowings under the Credit Facility and $3.7 million of undrawn letters of credit, all of which were commitments under the Credit Facility, leaving the Company with approximately $700 million of unused borrowing capacity under the Credit Facility. As of March 31, 2020, the Company was in compliance with its debt covenants.

Senior notes. The Company's 7.50% senior notes with a debt principal balance of $450 million matured and was repaid in January 2020. The Company funded the repayment with cash on hand. The Company's 3.45% senior notes, with a debt principal balance of $500 million, will mature in January 2021 and are included in the current portion of long-term debt in the consolidated balance sheet as of March 31, 2020.

See Note 17 for a discussion of the $905 million 364-day credit agreement entered into by the Company subsequent to March 31, 2020.

NOTE 8. Incentive Plans

Stock-based compensation expense is as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Restricted stock - Equity Awards	$	11	$	18
Restricted stock - Liability Awards (a)	—		5
Performance unit awards	4		5
Employee stock purchase plan	1		1
	$	16	$	29

______________________

(a)Liability Awards are expected to be settled on their vesting date in cash. As of March 31, 2020 and December 31, 2019, accounts payable – due to affiliates included $2 million and $11 million, respectively, of liabilities attributable to Liability Awards.

As of March 31, 2020, there was $97 million of unrecognized stock-based compensation expense related to unvested share-based compensation plans, including $10 million attributable to stock-based awards that are expected to be settled on their vesting date in cash, rather than in equity shares. The unrecognized compensation expense will be recognized on a straight-line basis over the remaining vesting periods of the awards, which is a period of less than three years on a weighted average basis.

21

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

Activity for outstanding restricted stock awards, performance units and stock options is as follows:

	Three Months Ended March 31, 2020
	Restricted Stock Equity Awards	Restricted Stock Liability Awards	Performance Units	Stock Options
Beginning incentive compensation awards	824,193	246,851	116,215	121,953
Awards granted	64,805	3,061	132,621	—
Awards forfeited	(6,219)	(2,568)	—	—
Awards vested (a)	(217,947)	(67,927)	—	—
Options exercised	—	—	—	(7,728)
Ending incentive compensation awards	664,832	179,417	248,836	114,225

______________________

(a)Per the terms of award agreements and elections, the issuance of common stock may be deferred for certain restricted stock equity awards, performance units and stock options that vest during the period.

NOTE 9. Asset Retirement Obligations

The changes in asset retirement obligations are as follows: 

	Three Months Ended March 31, 2020
	(in millions)
Beginning asset retirement obligations	$	191
New wells placed on production	1
Changes in estimates (a)	(5)
Liabilities settled	(16)
Accretion of discount	2
Ending asset retirement obligations	173
Less current portion of asset retirement obligations	(16)
Asset retirement obligations - noncurrent	$	157

______________________

(a)Changes in estimates are determined based on several factors, including abandonment cost estimates based on recent actual costs incurred to abandon wells, credit-adjusted risk-free discount rates, economic well life estimates and forecasted timing of abandoning wells.

NOTE 10. Commitments and Contingencies

Legal actions. The Company is a party to various proceedings and claims incidental to its business. While many of these matters involve inherent uncertainty, the Company believes that the amount of the liability, if any, ultimately incurred with respect to these proceedings and claims will not have a material adverse effect on the Company's consolidated financial position as a whole or on its liquidity, capital resources or future annual results of operations. The Company records reserves for contingencies when information available indicates that a loss is probable and the amount of the loss can be reasonably estimated.

Indemnifications. The Company has agreed to indemnify its directors and certain of its officers, employees and agents with respect to claims and damages arising from acts or omissions taken in such capacity, as well as with respect to certain litigation.

Environmental. Environmental expenditures that relate to an existing condition caused by past operations and that have no future economic benefits are expensed. Environmental expenditures that extend the life of the related property or mitigate or prevent future environmental contamination are capitalized. Liabilities for expenditures that will not qualify for capitalization are recorded when environmental assessment and/or remediation is probable and the costs can be reasonably estimated. Such

22

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

liabilities are undiscounted unless the timing of cash payments for the liability is fixed or reliably determinable. Environmental liabilities normally involve estimates that are subject to revision until settlement or remediation occurs.

Firm purchase, gathering, processing, transportation, fractionation and storage commitments. From time to time, the Company enters into, and as of March 31, 2020 was a party to, take-or-pay agreements, which include contractual commitments (i) to purchase sand and water for use in the Company's drilling operations, (ii) with midstream service companies and pipeline carriers for future gathering, processing, transportation, fractionation and storage and (iii) with oilfield services companies that provide drilling and pressure pumping services. These commitments are normal and customary for the Company's business activities.

Obligations following divestitures. In connection with its divestiture transactions, the Company may retain certain liabilities and provide the purchaser certain indemnifications, subject to defined limitations, which may apply to identified pre-closing matters, including matters of litigation, environmental contingencies, royalty and income taxes. Also associated with its divestiture transactions, the Company has issued and received guarantees to facilitate the transfer of contractual obligations, such as firm transportation agreements or gathering and processing arrangements. The Company does not recognize a liability if the fair value of the obligation is immaterial and the likelihood of making payments under these guarantees is remote.

South Texas Divestiture. In conjunction with the South Texas Divestiture, the Company transferred its long-term midstream agreements and associated MVC's to the buyer. However, the Company retained the obligation to pay 100 percent of any deficiency fees associated with the MVC's from January 2019 through July 2022. The buyer is required to reimburse the Company for 18 percent of the deficiency fees paid by the Company from January 2019 through July 2022; such reimbursement will be paid by the buyer in installments beginning in years 2023 through 2025. Assuming 100 percent of the MVC's are paid as deficiency fees, the maximum amount of future payments for this obligation would be approximately $471 million as of March 31, 2020. The Company's estimated deficiency fee obligation as of March 31, 2020 is $323 million, of which $130 million is included in other current liabilities in the consolidated balance sheets. The deficiency fee receivable from the buyer of $70 million is included in noncurrent other assets in the consolidated balance sheets. The Company has received credit support for the deficiency fee receivable and the contingent consideration of up to $325 million.

Raton transportation commitments. In July 2018, the Company completed the sale of its gas field assets in the Raton Basin to an unaffiliated third party and transferred certain gas transportation commitments, which extend through 2032, to the buyer for which the Company has provided a guarantee. Assuming 100 percent of the remaining commitments are paid by the Company under its guarantee, the maximum amount of future payments would be approximately $90 million as of March 31, 2020. The Company has received credit support for the commitments of up to $50 million. The Company paid $3 million in gas transportation fees associated with the transferred commitment for the three months ended March 31, 2020 and was fully reimbursed.

Certain contractual obligations were retained by the Company after the South Texas Divestiture, the divestiture of the Company's gas field assets in the Raton Basin, the divestiture of the Company's pressure pumping assets and the decommissioning of the Company's sand mine operations in Brady, Texas. These contracts were primarily related to firm transportation and storage agreements in which the Company is unlikely to realize any benefit. The estimated obligations associated with these agreements are included in other current or noncurrent liabilities in the consolidated balance sheets.

The changes in contract obligations are as follows:

	Three Months Ended March 31, 2020
	(in millions)
Beginning contract obligations	$	468
Liabilities settled	(152)
Accretion of discount	3
Changes in estimate (a)	66
Ending contract obligations	$	385

______________________

(a)Represents changes in the Company's forecasted deficiency fee payments associated with the South Texas Divestiture and the difference between estimated and actual liabilities settled.

23

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

NOTE 11. Related Party Transactions

In December 2018, the Company completed the sale of its pressure pumping assets to ProPetro in exchange for 16.6 million shares of ProPetro common stock and $110 million of cash that was received during the first quarter of 2019. ProPetro is considered a related party as the shares received represent 16 percent of ProPetro's outstanding common stock. In addition to the sale of equipment and related facilities, the Company entered into a long-term agreement with ProPetro for it to provide pressure pumping and related services. The costs of these services are capitalized in oil and gas properties as incurred.

In October 2019, Phillip A. Gobe, a nonemployee member of the Company's board of directors, was appointed by the board of directors of ProPetro to serve as its Executive Chairman, and in March 2020 he was appointed as Chief Executive Officer and Chairman of the Board of Directors. Mark S. Berg, the Company's Executive Vice President, Corporate Operations, continues to serve as a member of the ProPetro board of directors under the Company's right to designate a director to the board of directors of ProPetro so long as the Company owns five percent or more of ProPetro's outstanding common stock.

Transactions and balances with ProPetro are as follows:

	Three Months Ended March 31, 43921
	2020		2019
	(in millions)
Pressure pumping and related services charges	$	67	$	147

	As of March 31, 2020		As of December 31, 2019
	(in millions)
Accounts receivable - due from affiliate (a)	$	—	$	3
Accounts payable - due to affiliate (b)	$	89	$	88

____________________

(a)Represents employee-related charges that were reimbursed by ProPetro.

(b)Represents pressure pumping and related services provided by ProPetro as part of a long-term service agreement.

NOTE 12. Revenue Recognition

The Company recognizes revenue when control of the promised goods or services is transferred to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.

Disaggregated revenue from contracts with purchasers. Revenues on sales of oil, NGLs, gas and purchased oil and gas are recognized when control of the product is transferred to the purchaser and payment can be reasonably assured. Sales prices for oil, NGLs and gas production are negotiated based on factors normally considered in the industry, such as an index or spot price, distance from the well to the pipeline or market, commodity quality and prevailing supply and demand conditions. Accordingly, the prices of oil, NGLs and gas generally fluctuate based on the relevant market index rates.

24

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

Disaggregated revenue from contracts with purchasers by product type is as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Oil sales	$	924	$	917
NGL sales	111		138
Gas sales	60		80
Total oil and gas sales	1,095		1,135
Sales of purchased oil	902		1,107
Sales of purchased gas	13		2
Total sales of purchased oil and gas	915		1,109
Total revenue from contracts with purchasers	$	2,010	$	2,244

As of March 31, 2020 and December 31, 2019, the accounts receivable balance representing amounts due or billable under the terms of contracts with purchasers was $462 million and $968 million, respectively.

NOTE 13. Interest and Other Income (Loss), Net

The components of net interest and other income (loss) are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Interest income	$	2	$	8
Investment in affiliate valuation adjustment (Note 4)	(145)		174
Contingent consideration valuation adjustment (Note 4)	(63)		—
Deferred compensation plan income (loss)	(3)		7
Other	3		2
	$	(206)	$	191

25

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

 NOTE 14. Other Expense

The components of other expense are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
South Texas deficiency fee obligation (Note 4)	$	69	$	—
Termination and idle drilling and frac equipment charges (a)	8		4
Transportation commitment charges (b)	4		40
Legal and environmental charges	3		5
Restructuring charges (Note 3)	—		13
Asset impairment (Note 4)	—		28
Sand mine decommissioning-related charges (Note 3)	—		23
Vertical integration services (income) loss, net (c)	(4)		20
Other	5		14
	$	85	$	147

____________________

(a)Includes idle frac fleet fees, stacked drilling rig charges and drilling rig early termination charges.

(b)Primarily represents firm transportation payments on excess pipeline capacity commitments.

(c)For the three months ended March 31, 2019, amount includes $9 million of decommissioning operating expenses related to the Company's Brady sand mine and $15 million of carryover and winding down operating expenses related to the Company's sale of its pressure pumping services assets in December 2018. The components of the vertical integration services net margins are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Gross revenues	$	11	$	35
Gross costs and expenses	$	7	$	55

26

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

NOTE 15. Income Taxes

On March 27, 2020, President Trump signed into law the Coronavirus Aid, Relief and Economic Security Act ("CARES Act"). The CARES Act, among other things, includes provisions relating to refundable payroll tax credits, deferment of employer social security payments, net operating loss carryback periods, alternative minimum tax credit refunds, modifications to the net interest deduction limitations and technical corrections to tax depreciation methods for qualified improvement property. The Company continues to examine how the CARES Act may impact its business, results of operations, financial condition and liquidity.

Income tax provision and effective tax rate are as follows:

	Three Months Ended March 31,
	2020			2019
	(in millions)
Deferred tax provision	$	(76)		$	(103)
Effective tax rate	21		%	23		%

Uncertain tax positions. The Company recognizes the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained upon examination by the taxing authorities based upon the technical merits of the position. As of March 31, 2020 and December 31, 2019, the Company had unrecognized tax benefits ("UTBs") of $39 million for each respective period as a result of research and experimental expenditures related to horizontal drilling and completion innovations. If all or a portion of the UTBs is sustained upon examination by the taxing authorities, the tax benefit will be recorded as a reduction to the Company's deferred tax liability and will affect the Company's effective tax rate in the period it is recorded. The Company expects to substantially resolve the uncertainties associated with the UTBs within the next twelve months.

The Company files income tax returns in the U.S. federal and various state and foreign jurisdictions. The Internal Revenue Service has closed examinations of the 2011 and prior tax years and, with few exceptions, the Company believes that it is no longer subject to examinations by state and foreign tax authorities for years before 2012. As of March 31, 2020, no adjustments had been proposed in any jurisdiction that would have a significant effect on the Company's liquidity, future results of operations or financial position.

NOTE 16. Net Income Per Share

The components of basic and diluted net income per share attributable to common stockholders are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Net income attributable to common stockholders	$	289	$	350
Participating share-based earnings	(1)		(2)
Basic and diluted net income attributable to common stockholders	$	288	$	348
Basic and diluted weighted average shares outstanding	166		169

Stock repurchase program. In December 2018, the Company's board of directors authorized a $2 billion common stock repurchase program. Under this stock repurchase program, the Company may repurchase shares at management's discretion in accordance with applicable securities laws. In addition, the Company may repurchase shares pursuant to a trading plan meeting the requirements of Rule 10b5-1 under the Securities Act of 1934, which would permit the Company to repurchase shares at times that may otherwise be prohibited under the Company's insider trading policy. The stock repurchase program has no time limit and may be modified, suspended or terminated at any time by the board of directors.

27

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2020

(Unaudited)

Shares repurchased are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Share repurchases (a)	$	110	$	200

______________________

(a)During the three months ended March 31, 2020 and March 31, 2019, the Company repurchased 919,794 and 1,436,533 shares, respectively.

As of March 31, 2020, $1.1 billion remains available for use to repurchase shares under the Company's common stock repurchase program.

NOTE 17. Subsequent Events

Subsequent to March 31, 2020, the COVID-19 pandemic continues to significantly disrupt the demand for oil throughout the world. Although OPEC, Russia and other oil producing nations have agreed to oil production cuts, there is limited worldwide storage available and oil prices continue to decline. On April 20, 2020 WTI oil prices reached a record low of negative $37.63 per barrel. The length of this demand disruption is unknown, and there is significant uncertainty regarding the long-term impact to global oil demand, which is continuing to negatively impact the Company's results of operations and planned 2020 capital activities. In response to the uncertainty of the circumstances described above, the Company has enhanced its liquidity position through the following actions:

•On April 3, 2020, the Company entered into a 364-Day Credit Agreement (the "364-Day Credit Agreement") with Wells Fargo Bank, National Association, as Administrative Agent, and the other agents and lenders party thereto. The 364-Day Credit Agreement provides for an unsecured revolving credit facility with commitments in an aggregate amount of $905 million as of April 3, 2020. The 364-Day Credit Agreement and any loans provided thereunder will mature on April 2, 2021, provided that the Company may, at its election, extend the maturity date to April 1, 2022 to the extent that the lenders agree to such extension.

•The Company has continued to modify its derivative positions subsequent to March 31, 2020 to reduce the effects of oil price volatility on it results of operations. The table below shows the incremental changes to its derivative position shown in Note 5:

	2020						Year Ending December 31, 2021
	Second Quarter		Third Quarter		Fourth Quarter
WTI swap contracts:
Volume per day (Bbl)	42,033		—		—		—
Price per Bbl	$	21.50	$	—	$	—	$	—
NYMEX gas collar contracts:
Volume per day (MMBtu)	—		—		—		80,000
NYMEX price per MMBtu:
Call	$	—	$	—	$	—	$	3.15
Put	$	—	$	—	$	—	$	2.50

As of March 31, 2020, the Company was party to certain Brent oil swap contracts for 19,000 barrels per day for 2021 under which the Company would have received an average fixed price of $39.97 per barrel and paid a floating Brent price. Subsequent to March 31, 2020, such contracts were terminated, which is expected to result in the recognition of a $9 million gain in April 2020.

28

PIONEER NATURAL RESOURCES COMPANY

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Impact of the COVID-19 Pandemic and 2020 Plan Changes

The COVID-19 pandemic has resulted in a severe worldwide economic downturn, significantly disrupting the demand for oil throughout the world, and has created significant volatility, uncertainty and turmoil in the oil and gas industry. The decrease in demand for oil combined with the oil supply increase attributable to the battle for market share among OPEC, Russia and other oil producing nations, resulted in oil prices declining significantly beginning in late February 2020. The length of this demand disruption is unknown, and there is significant uncertainty regarding the long-term impact to global oil demand, which will ultimately depend on various factors and consequences beyond the Company’s control, such as the duration and scope of the pandemic, the length and severity of the worldwide economic downturn, additional actions by businesses and governments in response to both the pandemic and the decrease in oil prices, the speed and effectiveness of responses to combat the virus, and the time necessary to equalize oil supply and demand to restore oil pricing. In response to these developments, the Company has implemented measures to mitigate the impact of the COVID-19 pandemic on its employees, operations and financial position. These measures include, but are not limited to, the following:

Employee Safety. The Company has taken steps to keep its employees safe in light of the COVID-19 pandemic. These steps include closing the Company's offices, with the majority of employees working from home and essential field employees working on location, while adhering to additional health and safety protocols.

Expense Management. With the reduction in revenue, the Company has implemented, and will continue to implement cost saving initiatives, including:

•Reducing annual production costs by $60 million to $70 million and

•Reducing annual general and administrative and other overhead related costs by $80 million to $90 million, including through:

◦voluntary salary reductions by the Company's officers and board of directors;

◦reductions in estimated cash incentive compensation;

◦benefit reductions; and

◦other cash cost reductions.

Balance Sheet, Cash Flow and Liquidity. The Company has taken the following actions to strengthen its financial position and increase liquidity:

•Reduced its 2020 capital budget from a range of $3.15 billion to $3.45 billion to a range of $1.4 billion to $1.6 billion;

•Entered into a $905 million 364-day credit agreement, which is in addition to its existing $1.5 billion credit facility; and

•Increased its derivative positions to reduce the effects of oil price volatility on its net cash provided by operating activities.

The Company continues to assess the global impacts of the COVID-19 pandemic and expects to continue to modify its plans as more clarity around the full economic impact of COVID-19 becomes available. See "Risk Factors" for further discussion of the adverse impacts of the COVID-19 pandemic on the Company's business.

Financial and Operating Performance

The Company's financial and operating performance for the three months ended March 31, 2020 included the following highlights:

•Net income attributable to common stockholders for the three months ended March 31, 2020 was $289 million ($1.74 per diluted share) as compared to net income of $350 million ($2.06 per diluted share) for the same period in 2019. The primary components of the $61 million decrease in earnings attributable to common stockholders include:

•a $397 million decrease in net interest and other income (loss), primarily due to a $145 million noncash loss attributable to the decrease in the fair value of the Company's investment in affiliate and a $63 million noncash loss attributable to the decrease in the fair value of contingent consideration associated with the divestiture of the Company's Eagle Ford assets and other remaining South Texas assets in May 2019 ("South Texas Divestiture") during the three months ended March 31, 2020 as compared to a $174 million noncash gain attributable to the increase in fair value of the Company's investment in affiliate during the three months ended March 31, 2019;

29

PIONEER NATURAL RESOURCES COMPANY

•a $265 million decrease in net sales of purchased oil and gas due to a decrease in downstream oil margins on the Company's Gulf Coast refinery and export sales combined with declining oil prices during February and March 2020, which resulted in a $74 million loss on the sale of purchased oil inventory that was in transit or stored at the end of January and February 2020. The in-transit oil inventory was sold in February and March 2020 at lower prices as a result of declining oil demand attributable to the COVID-19 pandemic and the oversupply of oil due to the battle for market share among OPEC, Russia and other oil producing nations, that began in March 2020; and

•a $40 million decrease in oil and gas revenues due to a 15 percent decrease in average realized commodity prices per BOE, partially offset by a 13 percent increase in daily sales volumes due to the Company's successful horizontal drilling program in the Permian Basin;

partially offset by:

•a $466 million increase in net derivative gains, primarily due to changes in forward commodity prices and the cash settlement of derivative positions in accordance with their terms;

•a $62 million decrease in other expense, primarily due to a $69 million noncash charge for estimated deficiency payments related to the Company's South Texas Divestiture during the three months ended March 31, 2020 as compared to charges incurred during the three months ended March 31, 2019, which were primarily comprised of $75 million of charges associated with the Company's decommissioning of the Brady, Texas sand mine and pumping services asset sale and $40 million of unused transportation commitments;

•a $38 million decrease in production costs, including taxes, primarily attributable to (i) the Company's initiatives to reduce production costs, (ii) the sale of the Company's South Texas assets in May 2019 and (iii) the reduction in production taxes as a result of the aforementioned 15 percent decrease in average realized commodity prices per BOE, which were partially offset by the aforementioned increase in sales volumes;

•a $38 million decrease in general and administrative expense due to a reduction in headcount as a result of the Company's aforementioned Corporate Restructuring Program; and

•a $27 million decrease in the Company's income tax provision due to the decrease in earnings during the three months ended March 31, 2020 as compared to the same period in 2019.

•During the three months ended March 31, 2020, average daily sales volumes increased by 13 percent to 375,163 BOEPD, as compared to 333,430 BOEPD during the same period in 2019, due to the Company's successful Spraberry/Wolfcamp horizontal drilling program, which more than offset the loss of production associated with the Company's 2019 divestitures.

•Average oil, NGL and gas prices decreased per Bbl (for oil and NGLs) and Mcf (for gas) during the three months ended March 31, 2020 to $45.60, $14.52 and $1.61, respectively, as compared to $49.38, $22.79 and $2.50, respectively, for the same period in 2019.

•As of March 31, 2020 and December 31, 2019, the Company's net debt to book capitalization was 13 percent and 12 percent, respectively.

 Second Quarter 2020 Outlook

The second quarter is likely to be the most uncertain and disruptive quarter the industry has ever seen. The extent to which the Company’s future results are affected by the COVID-19 pandemic will depend on various factors and consequences beyond the Company’s control, such as the duration and scope of the pandemic, the length and severity of the worldwide economic downturn, additional actions by businesses and governments in response to both the pandemic and oil and gas prices, the speed and effectiveness of responses to combat the virus, and the time necessary to equalize oil supply and demand. As such, the Company has suspended its quarterly production guidance. However, Pioneer expects revised 2020 annual oil production to average 198,000 to 208,000 barrels per day and total production of 341,000 to 359,000 BOEs per day, which includes current voluntary curtailments of approximately 7,000 barrels of oil per day. The Company’s 2020 production outlook does not include the potential for any additional curtailments.

30

PIONEER NATURAL RESOURCES COMPANY

Based on current estimates, the Company expects the following operating and financial results for the second quarter of 2020:

	Three Months Ending June 30, 2020
	Guidance
	($ in millions, except per BOE amounts)
Production costs per BOE	$6.50 - $8.00
DD&A per BOE	$12.50 - $14.50
Exploration and abandonments expense	$5 - $15
General and administrative expense	$52 - $62
Accretion of discount on asset retirement obligations	$2 - $5
Interest expense	$25 - $30
Other expense	$20 - $30
Cash flow impact from firm transportation	($40) - ($10)
Current income tax provision	<$5
Effective tax rate	21% - 25%

For additional information on the risks posed by the COVID-19 pandemic, see "The COVID-19 pandemic and recent developments in the global oil markets have had, and may continue to have, material adverse consequences for general economic, financial and business conditions and for the Company's operations, financial condition, results of operations, cash flows and liquidity and those of its purchasers, suppliers and other counterparties" included in "Part II-Item 1A-Risk Factors" in this Quarterly Report on Form 10-Q.

Operations and Drilling Highlights

Average daily oil, NGL and gas sales volumes are as follows:

	Three Months Ended March 31, 2020
Oil (Bbls)	222,657
NGL (Bbls)	84,358
Gas (Mcf)	408,893
Total (BOE)	375,163

The Company's liquids production was 82 percent of total production on a BOE basis for both the three months ended March 31, 2020 and 2019.

Costs incurred are as follows:

	Three Months Ended March 31, 2020
	(in millions)
Unproved property acquisitions costs	$	4
Exploration costs	524
Development costs	72
Asset retirement obligations	(4)
	$	596

Development drilling activity is as follows:

	Three Months Ended March 31, 2020
Beginning wells in progress	5
Wells spud	3
Successful wells	(3)
Ending wells in progress	5

31

PIONEER NATURAL RESOURCES COMPANY

Exploration/extension drilling activity is as follows:

	Three Months Ended March 31, 2020
Beginning wells in progress	234
Wells spud	96
Successful wells	(83)
Ending wells in progress	247

The Company plans to operate an average five to eight drilling rigs and an average of two to three frac fleets in the Spraberry/Wolfcamp field during the last nine months of 2020. However, the scope, duration and magnitude of the direct and indirect effects of the COVID-19 pandemic are evolving rapidly and in ways that are difficult or impossible to anticipate. Given the dynamic nature of this situation, the Company is maintaining flexibility in its capital plan and will continue to evaluate drilling and completion activity on an economic basis, with future activity levels assessed monthly.

During the three months ended March 31, 2020, the Company successfully completed 60 horizontal wells in the northern portion of the play and 26 horizontal wells in the southern portion of the play. In the northern portion of the play, approximately 55 percent of the horizontal wells placed on production were Wolfcamp A interval wells, approximately 40 percent were Wolfcamp B interval wells and the remaining five percent were primarily Wolfcamp D interval wells. In the southern portion of the play, the majority of the wells placed on production were Wolfcamp A and B interval wells.

Results of Operations

Oil and gas revenues.

Average daily sales volumes are as follows: 

	Three Months Ended March 31,
	2020	2019	% Change
Oil (Bbls)	222,657	206,256	8	%
NGL (Bbls)	84,358	67,070	26	%
Gas (Mcf)	408,893	360,620	13	%
Total (BOEs)	375,163	333,430	13	%

The increase in average daily BOE sales volumes for the three months ended March 31, 2020, as compared to the same period in 2019 was due to the Company's successful Spraberry/Wolfcamp horizontal drilling program, which more than offset the loss of production associated with the Company's 2019 divestitures. The increase in NGL volumes also reflects new processing facilities being placed into service during 2019 and increased recovery rates for NGLs.

The oil, NGL and gas prices that the Company reports are based on the market prices received for each commodity. The average prices are as follows: 

	Three Months Ended March 31,
	2020		2019		% Change
Oil per Bbl	$	45.60	$	49.38	(8	%)
NGL per Bbl	$	14.52	$	22.79	(36	%)
Gas per Mcf	$	1.61	$	2.50	(36	%)
Total per BOE	$	32.08	$	37.84	(15	%)

Sales of purchased oil and gas. The Company enters into pipeline capacity commitments in order to secure available oil, NGL and gas transportation capacity from the Company's areas of production. The Company enters into purchase transactions with third parties and separate sale transactions with third parties to diversify a portion of the Company's oil and gas sales to Gulf Coast refineries and Gulf Coast and West Coast gas markets, international export markets and to satisfy unused gas pipeline capacity commitments. Revenues and expenses from these transactions are presented on a gross basis as the Company acts as a principal in the transaction by assuming both the risk and rewards of ownership, including credit risk, of the commodities purchased and the responsibility to deliver the commodities sold. The transportation costs associated with these transactions are presented on a net basis in purchased oil and gas expense.

32

PIONEER NATURAL RESOURCES COMPANY

The net effect of third party purchases and sales of oil and gas is as follows:

	Three Months Ended March 31,
	2020		2019		Change
	(in millions)
Sales of purchased oil and gas	$	915	$	1,109	$	(194)
Purchased oil and gas	1,028		957		71
Net effect on earnings	$	(113)	$	152	$	(265)

The $265 million decrease in net sales of purchased oil and gas for the three months ended March 31, 2020, as compared to the same period in 2019, was primarily due to (i) a decrease during the first quarter of 2020 downstream oil margins on the Company's Gulf Coast refinery and export sales and (ii) a $74 million loss during the first quarter of 2020 attributable to oil that was purchased and in transit via pipeline to the Gulf Coast or in Gulf Coast storage at the end of January and February, which was subsequently sold in February 2020 and March 2020, respectively, at lower prices. This oil inventory is sold in the following month at contracted prices that are generally tied to monthly average index oil prices (typically Brent oil prices). The significant decline in oil demand caused by the COVID-19 pandemic combined with the oil supply increase attributable to the battle for market share among OPEC, Russia and other oil producing nations resulted in oil prices declining significantly beginning in late February 2020. As a result of the decline in oil prices, the oil inventory in transit or stored at the end of January and February was sold in February and March, respectively, at lower prices resulting in the aforementioned loss.

Firm transportation payments on excess pipeline capacity are included in other expense in the accompanying consolidated statements of operations. See Note 14 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

Interest and other income (loss), net.

	Three Months Ended March 31,
	2020		2019		Change
	(in millions)
Interest and other income (loss), net	$	(206)	$	191	$	(397)

The decrease in interest and other income (loss) during the three months ended March 31, 2020, as compared to the same period in 2019, was primarily due to a $145 million noncash loss attributable to the decrease in the fair value of the Company's investment in affiliate and a $63 million noncash loss attributable to the decrease in the fair value of contingent consideration associated with the South Texas Divestiture during the three months ended March 31, 2020 as compared to a $174 million noncash gain attributable to the increase in the fair value on the Company's investment in affiliate during the three months ended March 31, 2019.

See Note 13 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

Derivative gain (loss), net.

	Three Months Ended March 31,
	2020		2019		Change
	(in millions)
Noncash derivative gain (loss), net	$	412	$	(17)	$	429
Cash receipts on settled derivative instruments, net	41		4		37
Derivative gain (loss), net	$	453	$	(13)	$	466

The Company primarily utilizes commodity swap contracts, collar contracts, collar contracts with short puts and basis swap contracts to (i) reduce the effect of price volatility on the commodities the Company produces and sells or consumes, (ii) support the Company's annual capital budgeting and expenditure plans and (iii) reduce commodity price risk associated with certain capital projects. The Company also, from time to time, utilizes interest rate contracts to reduce the effect of interest rate volatility on the Company's indebtedness.

33

PIONEER NATURAL RESOURCES COMPANY

Commodity derivatives and the relative price impact (per Bbl or Mcf) are as follows:

	Three Months Ended March 31,
	2020					2019
	Net cash receipts		Price impact			Net cash receipts (payments)		Price impact
	(in millions)					(in millions)
Oil derivative receipts	$	63	$	3.12	per Bbl	$	12	$	0.68	per Bbl
Gas derivative payments	—		$	—	per Mcf	(8)		$	(0.26)	per Mcf
Total net commodity derivative receipts	$	63				$	4

The Company's open derivative contracts are subject to continuing market risk. See "Item 3. Quantitative and Qualitative Disclosures About Market Risk" and Note 5 and Note 17 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

Oil and gas production costs.

	Three Months Ended March 31,
	2020		2019		Change
	(in millions)
Oil and gas production costs	$	176	$	221	$	(45)

Oil and gas production costs per BOE are as follows:

	Three Months Ended March 31,
	2020		2019		% Change
Lease operating expense per BOE (a)	$	3.32	$	5.12	(35)	%
Gathering, processing and transportation expense per BOE (b)	2.52		2.33		8	%
Workover costs per BOE (a)	0.44		0.87		(49)	%
Net natural gas plant income per BOE (c)	(1.14)		(0.96)		19	%
	$	5.14	$	7.36	(30)	%

_____________________

(a)Lease operating expense and workover expense represent the components of oil and gas production costs over which the Company has management control.

(b)Gathering, processing and transportation expense represents the costs to gather, process, fractionate and transport the Company's gas and NGLs to a point of sale.

(c)Net natural gas plant income represents the earnings from the Company's ownership share of gas processing facilities that gather and process the Company's and third party gas.

The decrease in lease operating expense per BOE for the three months ended March 31, 2020, as compared to the same period in 2019, was primarily attributable to (i) the Company's initiatives to reduce production costs and (ii) the sale of the Company's South Texas assets, which were divested in May 2019, and had a higher lease operating expense per BOE than the Company's Permian Basin assets. The net natural gas plant income per BOE primarily reflects increased throughput of volumes in gas processing facilities that the Company has an ownership interest due to additional gas plants being brought online in 2019. The decrease in workover costs per BOE was primarily due to the lower commodity prices in the first quarter of 2020 reducing the economic benefit of repairing many of the Company's marginal vertical wells.

Production and ad valorem taxes.

	Three Months Ended March 31,
	2020		2019		Change
	(in millions)
Production and ad valorem taxes	$	75	$	68	$	7

In general, production taxes and ad valorem taxes are directly related to commodity price changes; however, Texas ad valorem taxes are based upon prior year commodity prices, whereas production taxes are based upon current year commodity prices.

34

PIONEER NATURAL RESOURCES COMPANY

Production and ad valorem taxes per BOE are as follows:

	Three Months Ended March 31,
	2020		2019		% Change
Production taxes per BOE	$	1.44	$	1.70	(15)	%
Ad valorem taxes per BOE	0.73		0.56		30	%
	$	2.17	$	2.26	(4)	%

The decrease in production taxes per BOE for the three months ended March 31, 2020, as compared to the same period in 2019, was primarily due to the decrease in oil, NGL and gas prices. The increase in ad valorem taxes per BOE for the three months ended March 31, 2020, as compared to the same period in 2019, was primarily due to the higher commodity prices used to determine the assessed values of the Company's oil and gas properties in 2020.

Depletion, depreciation and amortization ("DD&A") expense.

	Three Months Ended March 31,
	2020		2019		Change
	(in millions)
Depletion, depreciation and amortization	$	434	$	421	$	13

Total DD&A expense per BOE is as follows:

	Three Months Ended March 31,
	2020		2019		% Change
DD&A per BOE	$	12.71	$	14.01	(9	%)
Depletion expense per BOE	$	12.09	$	13.20	(8	%)

The decrease in DD&A per BOE and depletion expense per BOE was primarily due to additions of proved reserves attributable to the Company's successful Spraberry/Wolfcamp horizontal drilling program.

Exploration and abandonments expense. Geological and geophysical costs, exploratory dry holes expenses and lease abandonments and other exploration expenses are as follows:

	Three Months Ended March 31,
	2020		2019		Change
	(in millions)
Geological and geophysical	$	7	$	20	$	(13)
Leasehold abandonments and other	2		—		2
	$	9	$	20	$	(11)

The decrease in geological and geophysical costs was primarily due to a decrease in geological and geophysical personnel costs as a result of the 2019 Corporate Restructuring Program. The increase in leasehold abandonments expense for the three months ended March 31, 2020, as compared to the same period in 2019, was primarily due to the abandonment of unproved properties that are not expected to be drilled.

During the three months ended March 31, 2020 and the same respective period in 2019, the Company drilled and evaluated 83 and 64 exploration/extension wells, respectively, of which both periods were 100 percent successfully completed as discoveries.

General and administrative expense.

	Three Months Ended March 31,
	2020		2019		Change
	(in millions)
General and administrative expense	$	56	$	94	$	(38)

Total general and administrative expense per BOE is as follows:

	Three Months Ended March 31,
	2020		2019		% Change
General and administrative expense per BOE	$	1.65	$	3.14	(47	%)

The decrease in general and administrative expense for the three months ended March 31, 2020, as compared to the same period in 2019, was primarily due to a decrease in corporate costs (primarily salaries, bonuses and benefits) as a result of the

35

PIONEER NATURAL RESOURCES COMPANY

Company's 2019 Corporate Restructuring Program and the Company's aforementioned cost reduction initiatives in response to the COVID-19 pandemic.

See Note 3 of Notes to Consolidated Financial Statements in "Item 1. Financial Statements" for additional information.

 Interest expense.

	Three Months Ended March 31,
	2020		2019		Change
	(in millions)
Interest expense	$	27	$	29	$	(2)

The weighted average interest rate on the Company's indebtedness for the three months ended March 31, 2020 was 4.2 percent, as compared to 5.3 percent for the same period in 2019.

See Note 7 of Notes to Consolidated Financial Statements in "Item 1. Financial Statements" for additional information.

Other expense.

	Three Months Ended March 31,
	2020		2019		Change
	(in millions)
Other expense	$	85	$	147	$	(62)

The decrease in other expense during the three months ended March 31, 2020, as compared to the same period in 2019, was primarily due to a $69 million increase in estimated deficiency payments related to the Company's South Texas Divestiture and $8 million of terminated drilling rig charges incurred during the three months ended March 31, 2020 as compared to $75 million of charges associated with the Company's decommissioning of the Brady, Texas sand mine and pumping services asset sale, $40 million of unused transportation commitments and $13 million of corporate restructuring charges associated with the 2019 Corporate Restructuring Program that were incurred during the three months ended March 31, 2019.

See Note 3 and Note 14 of Notes to Consolidated Financial Statements in "Item 1. Financial Statements" for additional information.

Income tax provision.

	Three Months Ended March 31,
	2020			2019			Change
	(in millions)
Income tax provision	$	76		$	103		$	(27)
Effective tax rate	21		%	23		%	(2		%)

The decrease in income tax provision during the three months ended March 31, 2020, as compared to the same period in 2019, was primarily due to an $88 million decrease in income before income taxes. See Note 15 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

Liquidity and Capital Resources

Liquidity. The COVID-19 pandemic has significantly affected the global economy, disrupted global supply chains and created significant volatility in the financial markets. In addition, the pandemic has resulted in travel restrictions, business closures and other restrictions that have disrupted the demand for oil throughout the world and when combined with the oil supply increase attributable to the battle for market share among OPEC, Russia and other oil producing nations, resulted in oil prices declining significantly beginning in late February 2020. The length of this demand disruption is unknown, and there is significant uncertainty regarding the long-term impact to global oil demand, which is negatively impacting the Company's results of operations and planned 2020 capital activities. During this period of uncertainty, the Company is focused on protecting its balance sheet and maintaining a strong liquidity position. The Company has taken steps to reduce, defer or cancel certain planned capital expenditures and reduce its overall cost structure commensurate with its expected level of activities. In addition, the Company has increased its derivative position since March 31, 2020 to reduce the effects of oil price volatility on its net cash provided by operating activities for the remainder of 2020 and 2021.

36

PIONEER NATURAL RESOURCES COMPANY

To provide incremental liquidity, on April 3, 2020, the Company entered into a 364-Day Credit Agreement (the "364-Day Credit Agreement") with Wells Fargo Bank, National Association, as Administrative Agent, and the other agents and lenders party thereto. The 364-Day Credit Agreement provides for an unsecured revolving credit facility with commitments in an aggregate amount of $905 million as of April 3, 2020. The 364-Day Credit Agreement and any loans provided thereunder will mature on April 2, 2021, provided that the Company may, at its election, extend the maturity date to April 1, 2022 to the extent that the lenders agree to such extension. The Company may at any time terminate or reduce the commitments under the revolving credit facility and prepay any loans made thereunder. In addition, the commitments will be permanently reduced and any loans then outstanding are subject to mandatory prepayment, in each case, in an amount equal to the aggregate amount of net cash proceeds from (i) any incurrence of indebtedness for borrowed money in excess of $50 million or (ii) any public or private offering of equity securities.

The Company's primary sources of short-term liquidity are (i) cash and cash equivalents, (ii) net cash provided by operating activities, (iii) sales of investments, (iv) unused borrowing capacity under its five-year credit facility that matures in October 2023, unless extended (the "Credit Facility") and the 364-Day Credit Agreement, (v) issuances of debt or equity securities and (vi) other sources, such as sales of nonstrategic assets.

As of March 31, 2020, the Company had $800 million of outstanding borrowings under its Credit Facility, leaving approximately $700 million of unused borrowing capacity. The Company was in compliance with all of its debt covenants as of March 31, 2020. The Company also had unrestricted cash on hand of $784 million as of March 31, 2020.

As of April 30, 2020, the Company had $800 million of outstanding borrowings under its Credit Facility, leaving approximately $700 million of unused borrowing capacity and no outstanding borrowings under its 364-Day Credit Agreement leaving $905 million of unused borrowing capacity. The Company also had unrestricted cash on hand of $641 million as of April 30, 2020, which reflects dividends of $90 million paid in April 2020.

The Company's primary needs for cash are for (i) capital expenditures, (ii) acquisitions of oil and gas properties, (iii) payments of contractual obligations, including debt maturities, (iv) dividends and share repurchases and (v) working capital obligations. Funding for these cash needs may be provided by any combination of the Company's sources of liquidity. Although the Company expects that its sources of funding will be adequate to fund its revised 2020 planned capital expenditures, dividend payments and provide adequate liquidity to fund other needs, no assurance can be given that such funding sources will be adequate to meet the Company's future needs.

2020 capital budget. In response to the uncertainty around the duration and overall impact to the Company caused by the COVID 19 pandemic, the Company has reduced its capital budget for 2020 to range from $1.4 billion to $1.6 billion, consisting of $1.3 billion to $1.5 billion for drilling and completion related activities, including tank batteries and salt water disposal facilities, and $100 million for water infrastructure; however, the Company's capital spending outlook for the year is and will remain uncertain and subject to further adjustment as the Company gains more clarity around the length of time it will take to overcome the demand destruction and resulting worldwide oversupply of oil attributable to the COVID-19 pandemic and the battle for market share among OPEC, Russia and other oil producing nations as well as post-pandemic economic conditions. The Company's capital expenditures for the three months ended March 31, 2020 were $620 million. The 2020 capital budget and actual capital expenditures exclude acquisitions, asset retirement obligations, capitalized interest, geological and geophysical general and administrative expense and corporate facilities.

Capital resources. Cash flows from operating, investing and financing activities are summarized below.

	Three Months Ended March 31,
	2020		2019		Change
	(in millions)
Net cash provided by operating activities	$	825	$	604	$	221
Net cash used in investing activities	$	(681)	$	(695)	$	(14)
Net cash provided by (used in) financing activities	$	9	$	(223)	$	232

Operating activities. The increase in net cash flow provided by operating activities for the three months ended March 31, 2020, as compared to the same period in 2019, was primarily due to (i) the Company's overall lower cost structure due to the 2019 Corporate Restructuring Program and the Company's cost reduction initiatives in response to the COVID-19 pandemic, (ii) a $350 million change in working capital due to decreased accounts receivables as a result of lower commodity prices offset by a decrease in accounts payable due to the aforementioned cost reduction initiatives and (iii) $37 million of incremental cash available from commodity derivatives, partially offset by decreases in the Company's oil and gas revenues and net purchases and sales as a result of decreases in commodity prices.

37

PIONEER NATURAL RESOURCES COMPANY

Investing activities. The decrease in net cash used in investing activities for the three months ended March 31, 2020 as compared to the same period in 2019, was primarily due to a decrease in additions to oil and gas properties and other assets and other property and equipment of $102 million and $29 million, respectively, as a result of the Company's cost reduction efforts, which was offset by decreases in proceeds from sales of investments and disposition of assets of $112 million and $5 million, respectively.

Financing activities. The Company's significant financing activities are as follows:

•2020: The Company (i) borrowed $800 million under the Credit Facility, (ii) repaid $450 million associated with the maturity of its 7.50% senior notes, (iii) paid $146 million of other liabilities, (iv) purchased $122 million of treasury stock and (v) paid dividends of $73 million.

•2019: The Company purchased $222 million of treasury stock.

Dividends/distributions. During the three months ended March 31, 2020, the Company paid a quarterly dividend of $73 million, or $0.44 per share. In February 2020, the board of directors declared an increased quarterly cash dividend of $0.55 per share, payable April 14, 2020, to stockholders of record on March 31, 2020. Future dividends are at the discretion of the Company's board of directors, and, if declared, the board of directors may change the dividend amount based on the Company's liquidity and capital resources at that time.

Off-balance sheet arrangements. From time to time, the Company enters into arrangements and transactions that can give rise to material off-balance sheet obligations of the Company. As of March 31, 2020, the material off-balance sheet arrangements and transactions that the Company had entered into included (i) firm purchase, transportation, storage and fractionation commitments, (ii) open purchase commitments and (iii) contractual obligations for which the ultimate settlement amounts are not fixed and determinable. The contractual obligations for which the ultimate settlement amounts are not fixed and determinable include (a) derivative contracts that are sensitive to future changes in commodity prices or interest rates, (b) gathering, processing (primarily treating and fractionation) and transportation commitments on uncertain volumes of future throughput, (c) open purchase commitments and (d) indemnification obligations following certain divestitures. Other than the off-balance sheet arrangements described above, the Company has no transactions, arrangements or other relationships with unconsolidated entities or other persons that are reasonably likely to materially affect the Company's liquidity or availability of or requirements for capital resources. The Company expects to enter into similar contractual arrangements in the future, including incremental derivative contracts and additional firm purchase, transportation, storage and fractionation arrangements, in order to support the Company's business plans. See "Contractual obligations" below and Note 10 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

Contractual obligations. The Company's contractual obligations include short and long-term debt, leases (primarily related to contracted drilling rigs, equipment and office facilities), capital funding obligations, derivative obligations, firm transportation, storage and fractionation commitments, minimum annual gathering, processing and transportation commitments and other liabilities (including retained obligations associated with divestitures and postretirement benefit obligations). Other joint owners in the properties operated by the Company could incur portions of the costs represented by these commitments.

Firm purchase, transportation, storage, fractionation, gathering and processing commitments represent take-or-pay agreements, which include (i) contractual commitments to purchase and process sand and purchase water for use in the Company's drilling operations, (ii) estimated fees on production throughput commitments and demand fees associated with volume delivery commitments and (iii) contractual commitments for drilling and pressure pumping services. The Company does not expect to be able to fulfill all of its short-term and long-term volume delivery obligations from projected production of available reserves; consequently, the Company plans to purchase third party volumes to satisfy its commitments if it is economic to do so; otherwise, it will pay demand/deficiency fees for any commitment shortfalls. In addition, as a result of the Company's revised 2020 capital expenditure plans in response to reduced worldwide oil demand related to the COVID-19 pandemic, the Company does not expect to be able to fully utilize all the equipment, services and goods for which it has contractual commitments. Consequently, the Company expects to pay stacking fees, termination fees, idle fees and/or minimum take or pay fees associated with such contractual commitments.

The Company's commodity derivative contracts are periodically measured and recorded at fair value and continue to be subject to market and credit risk. As of March 31, 2020, these contracts represented net assets of $423 million. The ultimate liquidation value of the Company's commodity derivatives will be dependent upon actual future commodity prices, which may differ materially from the inputs used to determine the derivatives' fair values as of March 31, 2020. See Note 5 and Note 17 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" and "Item 3. Quantitative and Qualitative Disclosures About Market Risk" for additional information.

38

PIONEER NATURAL RESOURCES COMPANY

New Accounting Pronouncements

The effects of new accounting pronouncements are discussed in Note 2 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements."

39

PIONEER NATURAL RESOURCES COMPANY

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

In the normal course of business, the Company's financial position is routinely subject to a variety of risks, including market risks associated with changes in commodity prices, interest rate movements on outstanding debt and credit risks. These risks are mitigated through the Company's risk management program, which includes the use of derivative financial instruments and selling purchased oil and gas outside of the Permian Basin. The following quantitative and qualitative information is provided about financial instruments to which the Company was a party as of March 31, 2020, and from which the Company may incur future gains or losses from changes in commodity prices or interest rates. The Company does not enter into any financial instruments, including derivatives, for speculative or trading purposes.

Interest rate risk. As of March 31, 2020, the Company had $800 million of variable rate debt outstanding under the Credit Facility that is exposed to interest rate risk. As of March 31, 2020, the Company had $1.8 billion of fixed rate long-term debt outstanding with a weighted average interest rate of 4.2 percent. Although changes in interest rates may affect the fair value of the Company's fixed rate long-term debt, any changes would not expose the Company to the risk of earnings or cash flow losses. The Company did not have any interest rate derivative instruments outstanding as of March 31, 2020, however it may enter into such instruments in the future to mitigate interest rate risk. See Note 4 and Note 7 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

The average forward LIBOR rates, as of March 31, 2020, based on market quotes were as follows:

	Year Ending December 31, 2020		Year Ending December 31, 2021		Year Ending December 31, 2022		Year Ending October 31, 2023
Average forward LIBOR rates on Credit Facility borrowings	0.40	%	0.38	%	0.44	%	0.49	%

Commodity price risk. The Company's primary market risk exposure is in the price it receives from the sale of its oil, NGLs and gas production. Realized pricing is volatile and is determined by market prices that fluctuate with changes in supply and demand for these products throughout the world. The price the Company receives for its production depends on many factors outside of the control of the Company, including differences in commodity pricing at the point of sale versus various index prices. Reducing the Company's exposure to price volatility helps secure funds to be used in its capital program and to fund general working capital needs, debt obligations, dividends and share repurchases, among other uses. The Company mitigates its commodity price risk through the use of derivative financial instruments and sales of purchased oil and gas.

Derivative financial instruments. The Company's decision on the quantity and price at which it executes derivative contracts is based in part on its view of current and future market conditions. The Company may choose not to enter into derivative positions for expected production if the commodity price forecast for certain time periods is deemed to be unfavorable. Additionally, the Company may choose to liquidate existing derivative positions prior to the expiration of their contractual maturity in order to monetize gain positions if it is anticipated that the commodity price forecast is expected to improve. Such proceeds can be used for the purpose of funding the Company's capital program, general working capital needs, debt obligations, dividends and share repurchases, among other uses. While derivative positions limit the downside risk of adverse price movements, they also limit future revenues from upward price movements. The Company manages commodity price risk with the following types of derivative contracts:

•Swaps. The Company receives a fixed price and pays a floating market price to the counterparty on a notional amount of sales volumes, thereby fixing the price for the commodity sold.

•Collars. Collar contracts provide minimum ("floor" or "long put") and maximum ("ceiling") prices on a notional amount of sales volumes, thereby allowing some price participation if the relevant index price closes above the floor price but below the ceiling price.

•Collar contracts with short put options. Collar contracts with short put options differ from other collar contracts by virtue of the short put option price, below which the Company's realized price will exceed the variable market prices by the long put-to-short put price differential.

•Basis swaps. Basis swap contracts fix the basis differentials between the index price at which the Company sells its production and the index price used in swap or collar contracts.

40

PIONEER NATURAL RESOURCES COMPANY

•Options. Selling individual call options can enhance the market price by the premium received or, alternatively, the premium received can be utilized to improve swap or collar contract prices. Purchased put options establish a minimum floor price (less any premiums paid) and allow participation in higher prices when prices close above the floor price.

The Company has entered into derivative contracts for forecasted 2020 and 2021 production; consequently, if commodity prices decline, the Company could realize lower prices for volumes not protected by the Company's derivative activities and could see a reduction in derivative contract prices on additional volumes in the future. As a result, the Company's internal cash flows will be negatively impacted by a reduction in commodity prices.

The average forward prices based on March 31, 2020 market quotes were as follows:

	2020						Year Ending December 31, 2021
	Second Quarter		Third Quarter		Fourth Quarter
Average forward Brent oil price per Bbl	$	29.42	$	35.34	$	37.56	$	40.38
Average forward NYMEX gas price per MMBtu	$	1.70	$	1.97	$	2.33	$	2.48
Permian Basin gas index swap contracts:
Average forward basis differential price per MMBtu (a)	$	(1.01)	$	(0.70)	$	(0.83)	$	(0.63)

The average forward prices based on May 7, 2020 market quotes are as follows:

	2020						Year Ending December 31, 2021
	Second Quarter		Third Quarter		Fourth Quarter
Average forward Brent oil price per Bbl	$	29.93	$	32.01	$	34.02	$	36.84
Average forward NYMEX gas price per MMBtu	$	1.89	$	2.20	$	2.60	$	2.70
Permian Basin gas index swap contracts:
Average forward basis differential price per MMBtu (a)	$	(0.28)	$	(0.31)	$	(0.45)	$	(0.50)

___________________

(a)Based on market quotes for basis differentials between the Permian Basin index price and the NYMEX Henry Hub index price.

See Note 4, Note 5 and Note 17 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for a description of the Company's open derivative positions and additional information.

Sales of purchased oil and gas. The Company enters into pipeline capacity commitments in order to secure available oil, NGLs and gas transportation capacity from the Company's areas of production. The Company enters into purchase transactions with third parties and separate sale transactions with third parties to diversify a portion of the Company's oil and gas sales to Gulf Coast refineries and Gulf Coast and West Coast gas markets, international export markets and to satisfy unused gas pipeline capacity commitments.

Credit risk. The Company's primary concentration of credit risks are associated with (i) the collection of receivables resulting from the sale of oil and gas production, the sale of purchased oil and gas and contingent consideration and deficiency fees due from the purchaser of the Company's Eagle Ford assets and other remaining assets in South Texas and (ii) the risk of a counterparty's failure to meet its obligations under derivative contracts with the Company.

The Company monitors exposure to counterparties primarily by reviewing credit ratings, financial criteria and payment history. Where appropriate, the Company obtains assurances of payment, such as a guarantee by the parent company of the counterparty or other credit support. The Company's oil and gas is sold to various purchasers who must be prequalified under the Company's credit risk policies and procedures. Historically, the Company's credit losses on oil and gas receivables have not been material.

The Company uses credit and other financial criteria to evaluate the credit standing of, and to select, counterparties to its derivative instruments. Although the Company does not obtain collateral or otherwise secure the fair value of its derivative instruments, associated credit risk is mitigated by the Company's credit risk policies and procedures.

41

PIONEER NATURAL RESOURCES COMPANY

The Company has entered into International Swap Dealers Association Master Agreements ("ISDA Agreements") with each of its derivative counterparties. The terms of the ISDA Agreements provide the Company and the counterparties with right of set off upon the occurrence of defined acts of default by either the Company or a counterparty to a derivative contract, whereby the party not in default may set off all derivative liabilities owed to the defaulting party against all derivative asset receivables from the defaulting party. See Note 5 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

42

PIONEER NATURAL RESOURCES COMPANY

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of disclosure controls and procedures. The Company's management, with the participation of its principal executive officer and principal financial officer, have evaluated, as required by Rule 13a-15(b) under the Securities Exchange Act of 1934 (the "Exchange Act"), the effectiveness of the Company's disclosure controls and procedures (as defined in Exchange Act Rule 13a-15(e)) as of the end of the period covered by this Report. Based on that evaluation, the principal executive officer and principal financial officer concluded that the Company's disclosure controls and procedures were effective, as of the end of the period covered by this Report, in ensuring that information required to be disclosed by the Company in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and forms, including that such information is accumulated and communicated to the Company's management, including the principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure.

Changes in internal control over financial reporting. There have been no changes in the Company's internal control over financial reporting (as defined in Rule 13a-15(f) under the Exchange Act) that occurred during the three months ended March 31, 2020 that have materially affected or are reasonably likely to materially affect the Company's internal control over financial reporting.

43

PIONEER NATURAL RESOURCES COMPANY

PART II. OTHER INFORMATION 

ITEM 1. LEGAL PROCEEDINGS

The Company is party to various proceedings and claims incidental to its business. While many of these matters involve inherent uncertainty, the Company believes that the amount of the liability, if any, ultimately incurred with respect to these proceedings and claims will not have a material adverse effect on the Company's consolidated financial position as a whole or on its liquidity, capital resources or future annual results of operations. 

ITEM 1A. RISK FACTORS

In addition to the information set forth in this report, the risks that are discussed in the Company's Annual Report on Form 10-K for the year ended December 31, 2019, under the headings "Part I, Item 1. Business – Competition, Markets and Regulations," "Part I, Item 1A. Risk Factors," "Part II, Item 7A. Quantitative and Qualitative Disclosures About Market Risk" should be carefully considered, as such risks could materially affect the Company's business, financial condition or future results. Other than described below, there has been no material change in the Company's risk factors that were described in the Company's 2019 Annual Report on Form 10-K.

These risks are not the only risks facing the Company. Additional risks and uncertainties not currently known to the Company or that it currently deems to be immaterial also may have a material adverse effect on the Company's business, financial condition or future results.

The COVID-19 pandemic and recent developments in the global oil markets have had, and may continue to have, material adverse consequences for general economic, financial and business conditions and for the Company's operations, financial condition, results of operations, cash flows and liquidity and those of its purchasers, suppliers and other counterparties.

The COVID-19 pandemic has significantly affected the global economy, disrupted global supply chains and created significant volatility in the financial markets. In addition, the pandemic has resulted in travel restrictions, business closures and other restrictions that has led to a significant reduction in demand for oil, NGL and gas, which, when combined with the oil supply increase attributable to the battle for market share among OPEC, Russia and other oil producing nations, has resulted in oil prices declining significantly beginning in late February 2020. For instance, on April 20, 2020, WTI oil prices reached a record low of negative $37.63 per barrel. As a result of the pandemic and low oil prices, the Company has reduced its 2020 drilling, completion, facilities and water infrastructure capital budget significantly in an effort to fund its budget fully from its forecasted cash flow. If the reduced demand for and prices of oil, NGL and gas, or the oversupply of oil, continue for a prolonged period, the Company may have to make further changes to its operations and capital budgets, and the Company's operations, financial condition, result of operations, cash flows and liquidity may be materially and adversely affected. Risks include, but are not limited to, the following:

•An extended decline in commodity prices could materially and adversely affect the amount of oil, NGL and gas that the Company can produce economically, which may result in (i) the Company having to make significant downward adjustments to its estimated proved reserves and (ii) a shortfall in expected cash flows, which could require the Company to reduce capital spending or borrow funds to cover any such shortfall. In addition, the continuation of depressed prices may adversely affect the ability of the Company to pay dividends or repurchase shares of common stock in the future.

•The reduced demand for oil, combined with the oversupply of oil, is expected to result in an oil surplus in the United States and worldwide. If the global demand for oil exports to foreign markets, or if the price that can be obtained in foreign markets does not support the transportation and other costs to reach those destinations, it may be uneconomical to invest in new wells and may cause the Company to shut in producing wells. The Company cannot assure whether shut-in wells can successfully return to pre-shut-in production levels or that the costs required to return the wells to production will be economical.

•The Company's ability to develop and sell its production could be materially and adversely affected by the inability or unwillingness of third parties to provide sufficient processing, fractionation, refining, transportation, storage or export facilities to the Company. For example, oil storage in the United States is at or nearing full capacity in many locations. Therefore, the Company's purchasers might decline to purchase the Company's oil, gas and NGLs, and the Company

44

PIONEER NATURAL RESOURCES COMPANY

may not be able to store its production. Such a lack of market for or storage capacity for the Company's products could require that the Company shut in some portion of its production. The amount of oil in storage may also keep oil prices at low levels for an extended period, even after demand begins to rise.

•Under Texas law, the Texas Railroad Commission is empowered to prorate oil production in the state based on market demand. If the Texas Railroad Commission finds that waste is taking place or is reasonably imminent, it is empowered to adopt a rule or order to correct, prevent, or lessen the waste. If the Texas Railroad Commission imposes proration in the future, or if any other similar laws or regulations are imposed, those restrictions would limit the amount of oil and gas the Company can produce.

•It is possible that any delay, reduction or curtailment of the Company's development and producing operations, whether due to regulatory actions or actions by the Company in reaction to market conditions, could result in the loss of acreage through lease expiration.

•Market conditions resulting from the effects of the COVID-19 pandemic, low oil prices, or a negative or recessionary economy could also increase the risk that the purchasers of the Company's production, lenders under its credit agreements, counterparties to its derivative instruments, and service providers may be unable to fulfil their obligations in a timely manner, or at all. If any such counterparty were to default on its obligations, such a default could have a material adverse effect on the Company's results of operations.

•The Company performs assessments of its proved and unproved oil and gas properties whenever events or circumstances indicate that the carrying values of those assets may not be recoverable. To the extent such tests indicate a reduction of the estimated useful life or estimated future cash flows of the Company's proved oil and gas properties, an impairment charge could be required to reduce the carrying value of its proved oil and gas properties to their fair value. In addition, goodwill is assessed for impairment whenever it is likely that events or circumstances indicate that the carrying value of a reporting unit exceeds its fair value. While the Company determined that its proved oil and gas properties and goodwill were not impaired as of March 31, 2020, with the significant uncertainty around the duration and overall impact of the effects of the COVID-19 pandemic coupled with ongoing oil market volatility, it is reasonably possible that the carrying value of its proved and unproved oil and gas properties or goodwill could be impaired. If incurred, an impairment of the Company's proved and unproved oil and gas properties or goodwill could have a material adverse effect on the Company's financial condition and results of operations.

•The Company's operations may be adversely affected if significant portions of its workforce are unable to work effectively, including because of illness, quarantines, social distancing, government actions, or other restrictions in connection with the COVID-19 pandemic. The Company has implemented workplace restrictions, including guidance for employees to work remotely for health and safety reasons, if possible. As some employees may have been or may in the future be placed in workplaces where exposure to COVID-19 is possible, the Company may be subject to risk of liability should such employees allege that the Company failed to adequately mitigate the risk of exposure to COVID-19, to the extent obligated to do so. In addition, in order to facilitate remote working arrangements, some employees are accessing workspaces from their personal devices through cloud-based systems, which could increase cybersecurity risks to the Company and to its employees. There can be no assurance that the Company's operations will not be curtailed or suspended or otherwise adversely affected due to such workforce issues.

The Company is not able to predict the ultimate impact of the COVID-19 pandemic on the Company's business, which will depend on numerous evolving factors and future developments that are beyond the Company's control, including the length of time that the pandemic continues, the speed and effectiveness of responses to combat the virus, the impact of the pandemic and its aftermath on the demand for oil, NGLs and gas, the response of the overall economy and the financial markets as well as the effect of governmental actions taken in response to the COVID-19 pandemic.

45

PIONEER NATURAL RESOURCES COMPANY

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Purchases of Equity Securities by the Issuer and Affiliated Purchasers

Purchases of the Company's common stock are as follows: 

	Three Months Ended March 31, 2020
Period	Total Number of Shares Purchased (a)	Average Price  Paid per Share		Total Number of Shares  Purchased As Part of Publicly Announced Plans or Programs	Approximate Dollar Amount of Shares that May Yet Be Purchased under Plans or Programs (b)
January 2020	25,852	$	150.53	—	$	1,250,690,958
February 2020	440,232	$	132.12	379,018	$	1,200,693,607
March 2020	540,820	$	110.95	540,776	$	1,140,693,850
	1,006,904			919,794

____________________

(a)Includes shares purchased from employees in order for employees to satisfy income tax withholding payments related to share-based awards that vested during the period.

(b)In December 2018, the Company's board of directors authorized a $2 billion common stock repurchase program.

46

PIONEER NATURAL RESOURCES COMPANY

ITEM 6. EXHIBITS

Exhibits

Exhibit Number	Description
10.1	364-Day Credit Agreement dated as of April 3, 2020, among the Company, as the Borrower, Wells Fargo Bank, National Association, as Administrative Agent, and certain other agents and lenders (incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K, File No. 1-13245, filed with the SEC on April 6, 2020).
31.1 (a)	Chief Executive Officer certification under Section 302 of Sarbanes-Oxley Act of 2002.
31.2 (a)	Chief Financial Officer certification under Section 302 of Sarbanes-Oxley Act of 2002.
32.1 (b)	Chief Executive Officer certification under Section 906 of Sarbanes-Oxley Act of 2002.
32.2 (b)	Chief Financial Officer certification under Section 906 of Sarbanes-Oxley Act of 2002.
101.INS (a)	Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH (a)	Inline XBRL Taxonomy Extension Schema Document.
101.CAL (a)	Inline XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF (a)	Inline XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB (a)	Inline XBRL Taxonomy Extension Label Linkbase Document.
101.PRE (a)	Inline XBRL Taxonomy Extension Presentation Linkbase Document.
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

____________________

(a)Filed herewith.

(b)Furnished herewith.

47

PIONEER NATURAL RESOURCES COMPANY

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this Report to be signed on its behalf by the undersigned hereto duly authorized.

	PIONEER NATURAL RESOURCES COMPANY
May 8, 2020	By:	/s/ Richard P. Dealy
		Richard P. Dealy
		Executive Vice President and Chief Financial Officer
May 8, 2020	By:	/s/ Margaret M. Montemayor
		Margaret M. Montemayor
		Vice President and Chief Accounting Officer

48

EX-31.1

EXHIBIT 31.1

CHIEF EXECUTIVE OFFICER CERTIFICATION

I, Scott D. Sheffield, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Pioneer Natural Resources Company;

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 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 registrant as of, and for, the periods presented in this report;

4.The registrant’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 registrant 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 registrant, 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 registrant’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 registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’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 registrant’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 registrant’s internal control over financial reporting.

/s/ Scott D. Sheffield
Scott D. Sheffield
President and Chief Executive Officer
Date:	May 8, 2020

EX-31.2

EXHIBIT 31.2

CHIEF FINANCIAL OFFICER CERTIFICATION

I, Richard P. Dealy, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Pioneer Natural Resources Company;

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 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 registrant as of, and for, the periods presented in this report;

4.The registrant’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 registrant 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 registrant, 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 registrant’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 registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’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 registrant’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 registrant’s internal control over financial reporting.

/s/ Richard P. Dealy
Richard P. Dealy
Executive Vice President and Chief Financial Officer
Date:	May 8, 2020

EX-32.1

EXHIBIT 32.1

CERTIFICATION OF

CHIEF EXECUTIVE OFFICER

OF PIONEER NATURAL RESOURCES COMPANY

PURSUANT TO 18 U.S.C. § 1350

I, Scott D. Sheffield, President and Chief Executive Officer of Pioneer Natural Resources Company (the “Company”), hereby certify that the accompanying Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2020 and filed with the Securities and Exchange Commission pursuant to Section 13(a) of the Securities Exchange Act of 1934 (the “Report”) by the Company fully complies with the requirements of that section.

I further certify that the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Scott D. Sheffield
Scott D. Sheffield
President and Chief Executive Officer
Date:	May 8, 2020

EX-32.2

EXHIBIT 32.2

CERTIFICATION OF

CHIEF FINANCIAL OFFICER

OF PIONEER NATURAL RESOURCES COMPANY

PURSUANT TO 18 U.S.C. § 1350

I, Richard P. Dealy, Executive Vice President and Chief Financial Officer of Pioneer Natural Resources Company (the “Company”), hereby certify that the accompanying Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2020 and filed with the Securities and Exchange Commission pursuant to Section 13(a) of the Securities Exchange Act of 1934 (the “Report”) by the Company fully complies with the requirements of that section.

I further certify that the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Richard P. Dealy
Richard P. Dealy
Executive Vice President and Chief Financial Officer
Date:	May 8, 2020

XML

Income Taxes

3 Months Ended

Mar. 31, 2020

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

On March 27, 2020, President Trump signed into law the Coronavirus Aid, Relief and Economic Security Act ("CARES Act"). The CARES Act, among other things, includes provisions relating to refundable payroll tax credits, deferment of employer social security payments, net operating loss carryback periods, alternative minimum tax credit refunds, modifications to the net interest deduction limitations and technical corrections to tax depreciation methods for qualified improvement property. The Company continues to examine how the CARES Act may impact its business, results of operations, financial condition and liquidity.

Income tax provision and effective tax rate are as follows:

	Three Months Ended March 31,
	2020			2019
	(in millions)
Deferred tax provision	$	(76)		$	(103)
Effective tax rate	21		%	23		%

Uncertain tax positions. The Company recognizes the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained upon examination by the taxing authorities based upon the technical merits of the position. As of March 31, 2020 and December 31, 2019, the Company had unrecognized tax benefits ("UTBs") of $39 million for each respective period as a result of research and experimental expenditures related to horizontal drilling and completion innovations. If all or a portion of the UTBs is sustained upon examination by the taxing authorities, the tax benefit will be recorded as a reduction to the Company's deferred tax liability and will affect the Company's effective tax rate in the period it is recorded. The Company expects to substantially resolve the uncertainties associated with the UTBs within the next twelve months.

The Company files income tax returns in the U.S. federal and various state and foreign jurisdictions. The Internal Revenue Service has closed examinations of the 2011 and prior tax years and, with few exceptions, the Company believes that it is no longer subject to examinations by state and foreign tax authorities for years before 2012. As of March 31, 2020, no adjustments had been proposed in any jurisdiction that would have a significant effect on the Company's liquidity, future results of operations or financial position.

XML

Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2020

Fair Value Disclosures [Abstract]

Schedule of assets and liabilities measured at fair value on a recurring basis

Assets and liabilities measured at fair value on a recurring basis are as follows:

	As of March 31, 2020
	Fair Value Measurement
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(in millions)
Assets:
Commodity price derivatives	$	—	$	429	$	—	$	429
Deferred compensation plan assets	64		—		—		64
Investment in affiliate	42		—		—		42
Contingent consideration	—		28		—		28
Total assets	106		457		—		563
Liabilities:
Commodity price derivatives	—		6		—		6
	$	106	$	451	$	—	$	557

	As of December 31, 2019
	Fair Value Measurement
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(in millions)
Assets:
Commodity price derivatives	$	—	$	32	$	—	$	32
Deferred compensation plan assets	85		—		—		85
Investment in affiliate	187		—		—		187
Contingent consideration	—		91		—		91
Total assets	272		123		—		395
Liabilities:
Commodity price derivatives	—		20		—		20
	$	272	$	103	$	—	$	375

Fair value and fair value adjustments, nonrecurring

The average oil price per barrel and gas price per thousand cubic feet utilized in the respective Management's Price Outlooks are as follows:

	As of March 31, 2020
	Oil		Gas
Management's Price Outlooks	$	42.84	$	2.49

Schedule of carrying values and financial instruments not carried at fair value

Carrying values and fair values of financial instruments that are not carried at fair value in the consolidated balance sheets are as follows:

	As of March 31, 2020				As of December 31, 2019
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(in millions)
Assets:
Cash and cash equivalents:
Cash (a)	$	784	$	784	$	631	$	631
Restricted cash (a)	$	74	$	74	$	74	$	74
Liabilities:
Current portion of long-term debt:
Senior notes (b)	$	499	$	500	$	450	$	451
Long-term debt:
Credit facility (c)	$	796	$	797	$	—	$	—
Senior notes (b)	1,344		1,397		1,839		1,995
Total	$	2,140	$	2,194	$	1,839	$	1,995

______________________

(a)Fair value approximates carrying value due to the short-term nature of the instruments.

(b)Fair value is determined using Level 2 inputs. The Company's senior notes are quoted, but not actively traded on major exchanges; therefore, fair value is based on periodic values as quoted on major exchanges.

(c)Fair value is determined using Level 2 inputs.

XML

Other Expense (Schedule of Components of Other Expense) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Restructuring Cost and Reserve [Line Items]
South Texas deficiency fee obligation	$ 69	$ 0
Idle drilling and well service equipment expense	8	4
Transportation commitment charges	4	40
Legal and environmental charges	3	5
Restructuring charges	0	13
Asset impairment	0	28
Accelerated depreciation	0	23
Vertical integration services (income) loss, net	(4)	20
Other	5	14
Other expense	85	147
Gross revenues	11	35
Gross costs and expenses	7	55
Employee severance
Restructuring Cost and Reserve [Line Items]
Restructuring charges	0	13
Sand mine
Restructuring Cost and Reserve [Line Items]
Accelerated depreciation	$ 23	9
Pressure pumping assets
Restructuring Cost and Reserve [Line Items]
Accelerated depreciation		$ 15

XML

Net Income Per Share (Reconciliation of Earnings Attributable to Common Stockholders, Basic and Diluted) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Earnings Per Share [Abstract]
Net income attributable to common stockholders	$ 289	$ 350
Participating share-based earnings	(1)	(2)
Basic and diluted net income attributable to common stockholders	$ 288	$ 348

XML

Derivative Financial Instruments (Schedule of Derivative Instruments) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Assets:
Net Fair Value Presented in the Consolidated Balance Sheet	$ 386	$ 32
Net Fair Value Presented in the Consolidated Balance Sheet	43	0
Liabilities:
Net Fair Value Presented in the Consolidated Balance Sheet	3	12
Derivatives	3	8
Derivatives not designated as hedging instruments | Commodity price derivatives | Derivatives - current
Assets:
Fair Value	386	32
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Fair Value Presented in the Consolidated Balance Sheet	386	32
Liabilities:
Fair Value	3	12
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Fair Value Presented in the Consolidated Balance Sheet	3	12
Derivatives not designated as hedging instruments | Commodity price derivatives | Derivatives - noncurrent
Assets:
Fair Value	43
Gross Amounts Offset in the Consolidated Balance Sheet	0
Net Fair Value Presented in the Consolidated Balance Sheet	(43)
Liabilities:
Fair Value	3	8
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Derivatives	3	8
Derivatives not designated as hedging instruments | Commodity price derivatives | Other assets - noncurrent
Assets:
Fair Value	28	91
Net Fair Value Presented in the Consolidated Balance Sheet	28	91
Derivatives not designated as hedging instruments | Contingent consideration | Other assets - noncurrent
Assets:
Gross Amounts Offset in the Consolidated Balance Sheet	$ 0	$ 0

XML

Fair Value Measurements (Narrative) (Details) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2020 USD ($)	Mar. 31, 2019 USD ($)	Dec. 31, 2019 USD ($)	May 31, 2019 USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
South Texas deficiency fee obligation	$ 69	$ 0
Market Capitalization	12,000		$ 25,000
Goodwill	261		$ 261
Fair value of reporting unit	$ 15,500
Excess of fair value over carrying value	27.00%
South Texas divestiture
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration				$ 450
Sand mine
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of inventory and other property and other equipment		13
Pressure pumping assets
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of inventory and other property and other equipment		$ 15
South Texas Divestiture
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration				$ 136
Annual discount rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration, cash payment, measurement input				0.036
Contingent consideration, cash receipt, measurement input				0.032

XML

Incentive Plans (Share Based Incentive Award Activity) (Details)	3 Months Ended
	Mar. 31, 2020 shares
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Beginning balance outstanding, shares	121,953
Awards granted, shares	0
Awards forfeited, shares	0
Awards exercised, shares	0
Awards exercised, shares	(7,728)
Ending balance outstanding, shares	114,225
Restricted Stock Equity Awards
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Beginning balance outstanding, shares	824,193
Awards granted, shares	64,805
Awards forfeited, shares	(6,219)
Awards vested, shares	(217,947)
Awards exercised, shares	0
Ending balance outstanding, shares	664,832
Restricted Stock Liability Awards
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Beginning balance outstanding, shares	246,851
Awards granted, shares	3,061
Awards forfeited, shares	(2,568)
Awards vested, shares	(67,927)
Awards exercised, shares	0
Ending balance outstanding, shares	179,417
Performance Units
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Beginning balance outstanding, shares	116,215
Awards granted, shares	132,621
Awards forfeited, shares	0
Awards vested, shares	0
Awards exercised, shares	0
Ending balance outstanding, shares	248,836

XML

Related Party Transactions (Details) - USD ($) shares in Millions, $ in Millions	1 Months Ended	3 Months Ended
	Dec. 31, 2018	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019
Related Party Transaction [Line Items]
Pressure pumping and related services charges		$ 67	$ 147
Accounts receivable - due from affiliate		0			$ 3
Accounts payable - due to affiliate		$ 89			$ 88
ProPetro | ProPetro
Related Party Transaction [Line Items]
Ownership percentage		16.00%
ProPetro | Pressure pumping assets | Sale of assets
Related Party Transaction [Line Items]
Shares received	16.6
Short-term receivable				$ 110

XML

Consolidated Statements of Equity - USD ($) $ in Millions	Total	Common Stock	Additional Paid-in Capital	Treasury Stock	Retained Earnings
Beginning Balance (shares) at Dec. 31, 2018		169,499,000
Beginning Balance at Dec. 31, 2018	$ 12,111	$ 2	$ 9,062	$ (423)	$ 3,470
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividends declared	(54)				(54)
Exercise of long-term incentive stock options		10,000
Exercise of long-term incentive stock options and employee stock purchases	0		(1)	1
Purchases of treasury stock (shares)		(1,594,000)
Purchases of treasury stock	(222)			(222)
Stock-based compensation costs:
Issued awards (shares)		507,000
Issued awards	0
Compensation costs included in net loss	24		24
Net income	350				350
Ending Balance (shares) at Mar. 31, 2019		168,422,000
Ending Balance at Mar. 31, 2019	12,209	$ 2	9,085	(644)	3,766
Stock-based compensation costs:
Purchases of treasury stock (shares)		1,594,000
Purchases of treasury stock	222			222
Issued awards (shares)		507,000
Issued awards	$ 0
Dividends declared per share	$ 0.32
Beginning Balance (shares) at Dec. 31, 2019		165,547,000
Beginning Balance at Dec. 31, 2019	$ 12,119	$ 2	9,161	(1,069)	4,025
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividends declared	$ (91)				(91)
Exercise of long-term incentive stock options	7,728	8,000
Exercise of long-term incentive stock options and employee stock purchases	$ 0		(1)	1
Purchases of treasury stock (shares)		(1,007,000)
Purchases of treasury stock	(122)			(122)
Stock-based compensation costs:
Issued awards (shares)		316,000
Issued awards	0
Compensation costs included in net loss	16		16
Net income	289				289
Ending Balance (shares) at Mar. 31, 2020		164,864,000
Ending Balance at Mar. 31, 2020	12,211	$ 2	$ 9,176	(1,190)	$ 4,223
Stock-based compensation costs:
Purchases of treasury stock (shares)		1,007,000
Purchases of treasury stock	122			$ 122
Issued awards (shares)		316,000
Issued awards	$ 0
Dividends declared per share	$ 0.55

XML

Net Income Per Share (Tables)

3 Months Ended

Mar. 31, 2020

Earnings Per Share [Abstract]

Reconciliation of earnings attributable to common stockholders, basic and diluted

The components of basic and diluted net income per share attributable to common stockholders are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Net income attributable to common stockholders	$	289	$	350
Participating share-based earnings	(1)		(2)
Basic and diluted net income attributable to common stockholders	$	288	$	348
Basic and diluted weighted average shares outstanding	166		169

XML

Revenue Recognition (Tables)

3 Months Ended

Mar. 31, 2020

Revenue from Contract with Customer [Abstract]

Disaggregation of revenue

Disaggregated revenue from contracts with purchasers by product type is as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Oil sales	$	924	$	917
NGL sales	111		138
Gas sales	60		80
Total oil and gas sales	1,095		1,135
Sales of purchased oil	902		1,107
Sales of purchased gas	13		2
Total sales of purchased oil and gas	915		1,109
Total revenue from contracts with purchasers	$	2,010	$	2,244

XML

Cover Page - shares	3 Months Ended
	Mar. 31, 2020	May 07, 2020
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2020
Document Transition Report	false
Entity File Number	1-13245
Entity Registrant Name	PIONEER NATURAL RESOURCES CO
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	75-2702753
Entity Address, Address Line One	777 Hidden Ridge
Entity Address, City or Town	Irving
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	75038
City Area Code	972
Local Phone Number	444-9001
Title of 12(b) Security	Common Stock, par value $.01 per share
Trading Symbol	PXD
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		164,863,215
Amendment Flag	false
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0001038357

XML

Basis of Presentation

3 Months Ended

Mar. 31, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

Basis of Presentation

Presentation. In the opinion of management, the unaudited interim consolidated financial statements of the Company as of March 31, 2020 and for the three months ended March 31, 2020 and 2019 include all adjustments and accruals, consisting only of normal, recurring adjustments and accruals necessary for a fair presentation of the results for the interim periods in conformity with generally accepted accounting principles in the United States ("GAAP"). The operating results for the three months ended March 31, 2020 are not necessarily indicative of results for a full year.

Certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted in accordance with the rules and regulations of the United States Securities and Exchange Commission (the "SEC"). These unaudited interim consolidated financial statements should be read together with the consolidated financial statements and notes thereto included in the Company's Annual Report on Form 10-K for the year ended December 31, 2019.

Use of estimates in the preparation of financial statements. Preparation of the Company's unaudited interim consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Depletion of oil and gas properties and evaluations for impairment of goodwill and proved and unproved oil and gas properties, in part, is determined using estimates of proved, probable and possible oil and gas reserves. There are numerous uncertainties inherent in the estimation of quantities of proved, probable and possible reserves and in the projection of future rates of production and the timing of development expenditures. Similarly, evaluations for impairment of proved and unproved oil and gas properties are subject to numerous uncertainties including, among others, estimates of future recoverable reserves and commodity price outlooks. Actual results could differ from the estimates and assumptions utilized.

Impact of the COVID-19 Pandemic. A novel strain of the coronavirus ("COVID-19") surfaced in late 2019 and has spread around the world, including to the United States. In March 2020, the World Health Organization declared COVID-19 a pandemic, and the President of the United States declared the COVID-19 outbreak a national emergency. The COVID-19 pandemic has significantly affected the global economy, disrupted global supply chains and created significant volatility in the financial markets. In addition, the COVID-19 pandemic has resulted in travel restrictions, business closures and other restrictions that have disrupted the demand for oil throughout the world and when combined with the oil supply increase attributable to the battle for market share among OPEC, Russia and other oil producing nations, resulted in oil prices declining significantly beginning late February 2020. The length of this demand disruption is unknown, and there is significant uncertainty regarding the long-term impact to global oil demand, which is negatively impacting the Company's results of operations and planned 2020 capital activities.

Adoption of new accounting standards. In June 2016, the FASB issued ASU 2016-13, "Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments" ("ASU 2016-13"). Effective January 1, 2020, the Company adopted ASU 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments prospectively. This ASU replaces the incurred loss impairment model with an expected credit loss impairment model for financial instruments, including trade receivables. The amendment requires entities to consider forward-looking information to estimate expected credit losses, resulting in earlier recognition of losses for receivables that are current or not yet due, which were not considered under the previous accounting guidance. The impact of the adoption of this ASU was not material.

The Company is exposed to credit losses primarily through sales of oil, NGLs, gas and purchased oil and gas. The Company’s expected loss allowance methodology for accounts receivable is developed using historical collection experience, current and future economic and market conditions and a review of the current status of customers' trade accounts receivables.

Due to the short-term nature of such receivables, the estimate of amount of accounts receivable that may not be collected is based on aging of the accounts receivable balances and the financial condition of customers. The Company’s monitoring activities include timely account reconciliation, dispute resolution, payment confirmation, consideration of customers' financial condition and macroeconomic conditions. Balances are written off when determined to be uncollectible. The Company considered the current and expected future economic and market conditions surrounding the COVID-19 pandemic and determined that the estimate of credit losses was not significantly impacted.

XML

Divestitures, Decommissioning and Restructuring Activities

3 Months Ended

Mar. 31, 2020

Discontinued Operations and Disposal Groups [Abstract]

Divestitures, Decommissioning and Restructuring Activities

Divestitures, Decommissioning and Restructuring Activities

Divestitures

In May 2019, the Company completed the sale of its Eagle Ford assets and other remaining assets in South Texas (the "South Texas Divestiture") to an unaffiliated third party in exchange for total consideration having an estimated fair value of $210 million, after normal closing adjustments. The fair value of the consideration included (i) net cash proceeds of $2 million, (ii) $136 million in contingent consideration and (iii) a $72 million receivable associated with estimated deficiency fees to be paid by the buyer.

Contingent Consideration. Per the terms of the purchase and sale agreement, the Company is entitled to receive contingent consideration of up to $450 million based on future annual oil and NGL prices during each of the five years from 2020 to 2024. The Company determined the fair value of the contingent consideration as of the date of the sale to be $136 million using an option pricing model. The fair value of the contingent consideration is included in noncurrent other assets in the consolidated balance sheets since, if earned, such consideration will be paid by the buyer in installments beginning in 2023 through 2025. The Company revalues the contingent consideration each reporting period and records the resulting valuation changes in net interest and other income (loss) in the consolidated statements of operations. The Company recorded a loss on valuation adjustment of $63 million for the three months ended March 31, 2020. The fair value of the contingent consideration was $28 million as of March 31, 2020. See Note 4, Note 5 and Note 13 for additional information.

Deficiency Fee Obligation. The Company transferred its long-term midstream agreements and associated minimum volume commitments ("MVC") to the buyer. However, the Company retained the obligation to pay 100 percent of any deficiency fees associated with the MVC from January 2019 through July 2022. The Company determined the fair value of the deficiency fee obligation as of the date of the sale to be $348 million using a probability weighted present value model. The deficiency fee obligation is included in current or noncurrent liabilities in the consolidated balance sheets, based on the timing of payments. In March 2020, the Company recorded a charge of $69 million in other expense for the three months ended March 31, 2020, due to changes in the Company's forecasted deficiency fee payments. The estimated remaining deficiency fee obligation was $323 million as of March 31, 2020. See Note 4, Note 10 and Note 14 for additional information.

Deficiency Fee Receivable. The buyer is required to reimburse the Company for 18 percent of the deficiency fees paid under the transferred midstream agreements from January 2019 through July 2022. Such reimbursement will be paid by the buyer in installments beginning in 2023 through 2025. The Company determined the fair value of the deficiency fee receivable as of the date of the sale to be $72 million using a credit risk-adjusted valuation model. The deficiency fee receivable is included in noncurrent other assets in the consolidated balance sheets. See Note 4 for additional information.

Restricted Cash. As of March 31, 2020, the Company has $74 million deposited in an escrow account to be used to fund future deficiency fee payments. The escrow account balance is included in restricted cash in the consolidated balance sheet as of March 31, 2020. Beginning in 2021, the required escrow balance will decline to $50 million and, to the extent that there is any remaining balance after the payment of deficiency fees, the balance will become unrestricted and revert to the Company on March 31, 2023.

Decommissioning

In November 2018, the Company announced plans to close its sand mine located in Brady, Texas and transition its proppant supply requirements to West Texas sand sources. During the three months ended March 31, 2019, the Company recorded $23 million of accelerated depreciation and $13 million of inventory and other property and equipment impairment charges associated with the sand mine closure. See Note 14 for additional information.

Restructuring

During 2019, the Company implemented a corporate restructuring program to align its cost structure with the needs of a Permian Basin-focused company. The restructuring occurred in three phases (collectively, the "Corporate Restructuring Program") as follows:

•In March 2019, the Company made certain changes to its leadership and organizational structure, which included the early retirement and departure of certain officers of the Company,

•In April 2019, the Company adopted a voluntary separation program ("VSP") for certain eligible employees, and

•In May 2019, the Company implemented an involuntary separation program ("ISP").

The employee-related costs associated with the restructuring were primarily recorded in other expense in the consolidated statements of operations. Obligations associated with employee-related charges are included in accounts payable - due to affiliates in the consolidated balance sheets. See Note 14 for additional information.

The changes in the Company's total employee-related obligations are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Beginning employee-related obligations	$	6	$	27
Additions (Note 14)	—		13
Cash payments	(5)		(10)
Noncash changes	—		(4)
Ending employee-related obligations	$	1	$	26

XML

Long-term Debt

3 Months Ended

Mar. 31, 2020

Debt Disclosure [Abstract]

Long-term Debt

Long-term Debt

Credit facility. The Company's long-term debt consists of senior notes, a revolving corporate credit facility (the "Credit Facility") and the effects of issuance costs and discounts. The Credit Facility is maintained with a syndicate of financial institutions and has aggregate loan commitments of $1.5 billion. The Credit Facility has a maturity date in October 2023. As of March 31, 2020, the Company had $800 million of outstanding borrowings under the Credit Facility and $3.7 million of undrawn letters of credit, all of which were commitments under the Credit Facility, leaving the Company with approximately $700 million of unused borrowing capacity under the Credit Facility. As of March 31, 2020, the Company was in compliance with its debt covenants.

Senior notes. The Company's 7.50% senior notes with a debt principal balance of $450 million matured and was repaid in January 2020. The Company funded the repayment with cash on hand. The Company's 3.45% senior notes, with a debt principal balance of $500 million, will mature in January 2021 and are included in the current portion of long-term debt in the consolidated balance sheet as of March 31, 2020.

See Note 17 for a discussion of the $905 million 364-day credit agreement entered into by the Company subsequent to March 31, 2020.

XML

Related Party Transactions

3 Months Ended

Mar. 31, 2020

Related Party Transactions [Abstract]

Related Party Transactions

Related Party Transactions

In December 2018, the Company completed the sale of its pressure pumping assets to ProPetro in exchange for 16.6 million shares of ProPetro common stock and $110 million of cash that was received during the first quarter of 2019. ProPetro is considered a related party as the shares received represent 16 percent of ProPetro's outstanding common stock. In addition to the sale of equipment and related facilities, the Company entered into a long-term agreement with ProPetro for it to provide pressure pumping and related services. The costs of these services are capitalized in oil and gas properties as incurred.

In October 2019, Phillip A. Gobe, a nonemployee member of the Company's board of directors, was appointed by the board of directors of ProPetro to serve as its Executive Chairman, and in March 2020 he was appointed as Chief Executive Officer and Chairman of the Board of Directors. Mark S. Berg, the Company's Executive Vice President, Corporate Operations, continues to serve as a member of the ProPetro board of directors under the Company's right to designate a director to the board of directors of ProPetro so long as the Company owns five percent or more of ProPetro's outstanding common stock.

Transactions and balances with ProPetro are as follows:

	Three Months Ended March 31, 43921
	2020		2019
	(in millions)
Pressure pumping and related services charges	$	67	$	147

	As of March 31, 2020		As of December 31, 2019
	(in millions)
Accounts receivable - due from affiliate (a)	$	—	$	3
Accounts payable - due to affiliate (b)	$	89	$	88

____________________

(a)Represents employee-related charges that were reimbursed by ProPetro.

(b)Represents pressure pumping and related services provided by ProPetro as part of a long-term service agreement.

XML

Asset Retirement Obligations (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning asset retirement obligations	$ 191
New wells placed on production	1
Changes in estimate	(5)
Liabilities settled	(16)
Accretion of discount	2	$ 3
Ending asset retirement obligations	173
Asset Retirement Obligation, Current	16
Asset retirement obligations - noncurrent	$ 157

XML

Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	$ 2,010	$ 2,244
Oil sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	924	917
NGL sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	111	138
Gas sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	60	80
Total oil and gas sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	1,095	1,135
Sales of purchased oil
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	902	1,107
Sales of purchased gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	13	2
Total sales of purchased oil and gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	$ 915	$ 1,109

XML

Organization and Nature of Operations	3 Months Ended
	Mar. 31, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Nature of Operations	Organization and Nature of OperationsPioneer Natural Resources Company ("Pioneer" or the "Company") is a Delaware corporation whose common stock is listed and traded on the New York Stock Exchange. The Company is a large independent oil and gas exploration and production company that explores for, develops and produces oil, natural gas liquids ("NGLs") and gas in the Permian Basin in West Texas.

XML

Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Revenues and other income:
Revenue	$ 2,010	$ 2,244
Interest and other income (loss), net	(206)	191
Derivative gain (loss), net	453	(13)
Loss on disposition of assets, net	0	(9)
Total revenues and other income	2,257	2,413
Costs and expenses:
Production and ad valorem taxes	75	68
Depletion, depreciation and amortization	434	421
Exploration and abandonments	9	20
General and administrative	56	94
Accretion of discount on asset retirement obligations	2	3
Interest	27	29
Other	85	147
Costs and Expenses	1,892	1,960
Income before income taxes	365	453
Income tax provision	76	103
Net income attributable to common stockholders	$ 289	$ 350
Net income per share attributable to common stockholders:
Basic and diluted net income per share attributable to common stockholders	$ 1.74	$ 2.06
Weighted average shares outstanding:
Basic and diluted weighted average shares outstanding	166	169
Dividends declared per share	$ 0.55	$ 0.32
Oil and gas
Revenues and other income:
Revenue	$ 1,095	$ 1,135
Costs and expenses:
Costs and expenses	176	221
Sales of purchased oil and gas
Revenues and other income:
Revenue	915	1,109
Costs and expenses:
Costs and expenses	$ 1,028	$ 957

XML

Income Taxes (Tables)

3 Months Ended

Mar. 31, 2020

Income Tax Disclosure [Abstract]

Schedule of income tax provision and effective tax rate

Income tax provision and effective tax rate are as follows:

	Three Months Ended March 31,
	2020			2019
	(in millions)
Deferred tax provision	$	(76)		$	(103)
Effective tax rate	21		%	23		%

XML

Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2020

Related Party Transactions [Abstract]

Schedule of related party transactions and balances

Transactions and balances with ProPetro are as follows:

	Three Months Ended March 31, 43921
	2020		2019
	(in millions)
Pressure pumping and related services charges	$	67	$	147

	As of March 31, 2020		As of December 31, 2019
	(in millions)
Accounts receivable - due from affiliate (a)	$	—	$	3
Accounts payable - due to affiliate (b)	$	89	$	88

____________________

(a)Represents employee-related charges that were reimbursed by ProPetro.

(b)Represents pressure pumping and related services provided by ProPetro as part of a long-term service agreement.

XML

Revenue Recognition

3 Months Ended

Mar. 31, 2020

Revenue from Contract with Customer [Abstract]

Revenue Recognition

Revenue Recognition

The Company recognizes revenue when control of the promised goods or services is transferred to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.

Disaggregated revenue from contracts with purchasers. Revenues on sales of oil, NGLs, gas and purchased oil and gas are recognized when control of the product is transferred to the purchaser and payment can be reasonably assured. Sales prices for oil, NGLs and gas production are negotiated based on factors normally considered in the industry, such as an index or spot price, distance from the well to the pipeline or market, commodity quality and prevailing supply and demand conditions. Accordingly, the prices of oil, NGLs and gas generally fluctuate based on the relevant market index rates.

Disaggregated revenue from contracts with purchasers by product type is as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Oil sales	$	924	$	917
NGL sales	111		138
Gas sales	60		80
Total oil and gas sales	1,095		1,135
Sales of purchased oil	902		1,107
Sales of purchased gas	13		2
Total sales of purchased oil and gas	915		1,109
Total revenue from contracts with purchasers	$	2,010	$	2,244

As of March 31, 2020 and December 31, 2019, the accounts receivable balance representing amounts due or billable under the terms of contracts with purchasers was $462 million and $968 million, respectively.

XML

Fair Value Measurements

3 Months Ended

Mar. 31, 2020

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

The Company determines fair value based on the price that would be received from selling an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are based upon inputs that market participants use in pricing an asset or liability, which are characterized according to a hierarchy that prioritizes those inputs based on the degree to which they are observable. Observable inputs represent market data obtained from independent sources, whereas unobservable inputs reflect a company's own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. The fair value input hierarchy level to which an asset or liability measurement in its entirety falls is determined based on the lowest level input that is significant to the measurement in its entirety.

The three input levels of the fair value hierarchy are as follows:

•Level 1 – quoted prices for identical assets or liabilities in active markets.

•Level 2 – quoted prices for similar assets or liabilities in active markets; quoted prices for identical or similar assets or liabilities in markets that are not active; inputs other than quoted prices that are observable for the asset or liability (e.g. interest rates) and inputs derived principally from or corroborated by observable market data by correlation or other means.

•Level 3 – unobservable inputs for the asset or liability, typically reflecting management's estimate of assumptions that market participants would use in pricing the asset or liability. The fair values are therefore, determined using model-based techniques, including discounted cash flow models.

Assets and liabilities measured at fair value on a recurring basis. Assets and liabilities measured at fair value on a recurring basis are as follows:

	As of March 31, 2020
	Fair Value Measurement
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(in millions)
Assets:
Commodity price derivatives	$	—	$	429	$	—	$	429
Deferred compensation plan assets	64		—		—		64
Investment in affiliate	42		—		—		42
Contingent consideration	—		28		—		28
Total assets	106		457		—		563
Liabilities:
Commodity price derivatives	—		6		—		6
	$	106	$	451	$	—	$	557

	As of December 31, 2019
	Fair Value Measurement
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(in millions)
Assets:
Commodity price derivatives	$	—	$	32	$	—	$	32
Deferred compensation plan assets	85		—		—		85
Investment in affiliate	187		—		—		187
Contingent consideration	—		91		—		91
Total assets	272		123		—		395
Liabilities:
Commodity price derivatives	—		20		—		20
	$	272	$	103	$	—	$	375

Commodity price derivatives. The Company's commodity price derivatives represent oil, NGL and gas swap contracts, collar contracts, collar contracts with short puts and basis swap contracts. The asset and liability measurements for the Company's commodity price derivative contracts are determined using Level 2 inputs. The Company utilizes discounted cash flow and option-pricing models for valuing its commodity price derivatives.

The asset and liability values attributable to the Company's commodity price derivatives were determined based on inputs that include (i) the contracted notional volumes, (ii) independent active market price quotes, (iii) the applicable estimated

credit-adjusted risk-free rate yield curve and (iv) the implied rate of volatility inherent in the collar contracts and collar contracts with short puts, which is based on active and independent market-quoted volatility factors.

Deferred compensation plan assets. The Company's deferred compensation plan assets include investments in equity and mutual fund securities that are actively traded on major exchanges. The fair value of these investments is determined using Level 1 inputs based on observable prices on major exchanges.

Investment in affiliate. The Company elected the fair value option for measuring its equity method investment in ProPetro Holding Corp. ("ProPetro"). The fair value of its investment in ProPetro is determined using Level 1 inputs based on observable prices on a major exchange. See Note 11 and Note 13 for additional information.

Contingent consideration. The Company has a right to receive contingent consideration in conjunction with the South Texas Divestiture of up to $450 million based on future oil and NGL prices during each of the five years from 2020 to 2024. The fair value of the contingent consideration is determined using Level 2 inputs based on an option pricing model using quoted future commodity prices based on active markets, implied volatility factors and counterparty credit risk assessments. See Note 3, Note 5 and Note 13 for additional information. 

Assets and liabilities measured at fair value on a nonrecurring basis. Certain assets and liabilities are measured at fair value on a nonrecurring basis. These assets and liabilities are not measured at fair value on an ongoing basis, but are subject to fair value adjustments in certain circumstances. These assets and liabilities can include inventory, proved and unproved oil and gas properties, goodwill and other long-lived assets that are written down to fair value when they are impaired or held for sale.

Other assets. During the three months ended March 31, 2019, the Company impaired $13 million of inventory and other property and equipment related to the decommissioning of the Company's Brady, Texas sand mine, as these assets had no remaining future economic value. In addition, the Company recognized a $15 million impairment charge related to pressure pumping assets that were excluded from the December 2018 sale of the Company's pumping services assets. See Note 14 for additional information.

South Texas Divestiture. The Company recorded a deficiency fee obligation and related deficiency fee receivable in conjunction with the 2019 South Texas Divestiture. The fair value of the deficiency fee obligation and deficiency fee receivable was determined using Level 3 inputs based on a probability-weighted forecast that considers historical results, market conditions and various development plans to arrive at the estimated present value of the deficiency payments and corresponding receipts. The change to the Company's forecasted deficiency fee obligation, as a result of the expected impact of the COVID-19 pandemic on the ability of the buyer to satisfy the MVC, resulted in the Company recording a charge of $69 million to other expense for the three months ended March 31, 2020. The present value of the future cash payments and expected cash receipts were determined using a 3.6 percent and 3.2 percent discount rate, respectively, based on the estimated timing of future payments and receipts and the Company's counterparty credit risk assessments. See Note 3, Note 10 and Note 14 for additional information.

Impact of the COVID-19 pandemic on certain assets and liabilities measured at fair value on a nonrecurring basis.

Proved Properties. The Company performs assessments of its proved oil and gas properties accounted for under the successful efforts method of accounting, whenever events or circumstances indicate that the carrying value of those assets may not be recoverable. An impairment loss is indicated if the sum of the expected future cash flows, including from vertical integrated services that are used in the development of the assets, is less than the carrying amount of the assets, including the carrying value of the vertical integrated services and operating lease right-of-use assets. In these circumstances, the Company recognizes an impairment charge for the amount by which the carrying amount of the assets exceeds the estimated fair value of the assets.

Due to the decrease in management's commodity price outlooks during the first quarter of 2020, which represent longer-term outlooks that are developed based on third party longer term commodity price estimates as of a measurement date ("Management's Price Outlooks"), the Company performed an impairment assessment of its proved oil and gas properties as of March 31, 2020 and determined that its proved oil and gas properties were not impaired. The primary factors that may affect estimates of future cash flows for the Company's proved oil and gas properties are (i) future reserve adjustments, both positive and negative, to proved reserves and appropriate risk-adjusted probable and possible reserves, (ii) results of future drilling activities, (iii) Management's Price Outlooks and (iv) increases or decreases in production and capital costs. The average oil price per barrel and gas price per thousand cubic feet utilized in the respective Management's Price Outlooks are as follows:

	As of March 31, 2020
	Oil		Gas
Management's Price Outlooks	$	42.84	$	2.49

Goodwill. Goodwill is assessed for impairment whenever it is likely that events or circumstances indicate the carrying value of a reporting unit exceeds its fair value, but no less often than annually. An impairment charge is recorded for the amount by which the carrying amount exceeds the fair value of a reporting unit in the period it is determined to be impaired.

During the three months ended March 31, 2020 the Company's market capitalization decreased from $25 billion at December 31, 2019 to $12 billion at March 31, 2020. The Company determined that the significant decline in its market capitalization during the first quarter of 2020 indicated that an impairment loss on the Company's $261 million carrying amount of goodwill may have been incurred. Based on the Company's assessment of the fair value of goodwill as of March 31, 2020, the Company determined that its goodwill was not impaired. The fair value of the Company's reporting unit, as of March 31, 2020, was $15.5 billion, calculated as the Company's market capitalization plus a control premium, which is 27 percent in excess of the March 31, 2020 carrying value of the Company's reporting unit. A further decline in the Company’s share price for a sustained period of time, or a significant decrease in the future cash flows from the Company's proved oil and gas reserves, among other factors, could significantly impact the impairment analysis and may result in future goodwill impairment charges.

There is significant uncertainty surrounding the long-term impact to global oil demand due to the effects of the COVID-19 pandemic, coupled with significant excess oil supply that is rapidly filling worldwide storage. These conditions are negatively impacting the Company's 2020 forecasted capital activities and production levels. It is reasonably possible that the carrying value of the Company's proved oil and gas properties or goodwill could exceed their estimated fair value resulting in the need to impair their carrying values in the future. If incurred, an impairment of the Company's proved oil and gas properties or goodwill could have a material adverse effect on the Company's financial condition and results of operation.

Financial instruments not carried at fair value. Carrying values and fair values of financial instruments that are not carried at fair value in the consolidated balance sheets are as follows:

	As of March 31, 2020				As of December 31, 2019
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(in millions)
Assets:
Cash and cash equivalents:
Cash (a)	$	784	$	784	$	631	$	631
Restricted cash (a)	$	74	$	74	$	74	$	74
Liabilities:
Current portion of long-term debt:
Senior notes (b)	$	499	$	500	$	450	$	451
Long-term debt:
Credit facility (c)	$	796	$	797	$	—	$	—
Senior notes (b)	1,344		1,397		1,839		1,995
Total	$	2,140	$	2,194	$	1,839	$	1,995

______________________

(a)Fair value approximates carrying value due to the short-term nature of the instruments.

(b)Fair value is determined using Level 2 inputs. The Company's senior notes are quoted, but not actively traded on major exchanges; therefore, fair value is based on periodic values as quoted on major exchanges.

(c)Fair value is determined using Level 2 inputs.

The Company has other financial instruments consisting primarily of receivables, payables, other current assets and liabilities that approximate fair value due to the nature of the instrument and their relatively short maturities. Non-financial assets and liabilities initially measured at fair value include assets acquired and liabilities assumed in a business combination, goodwill and asset retirement obligations.

XML

Incentive Plans

3 Months Ended

Mar. 31, 2020

Compensation Related Costs [Abstract]

Incentive Plans

Incentive Plans

Stock-based compensation expense is as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Restricted stock - Equity Awards	$	11	$	18
Restricted stock - Liability Awards (a)	—		5
Performance unit awards	4		5
Employee stock purchase plan	1		1
	$	16	$	29

______________________

(a)Liability Awards are expected to be settled on their vesting date in cash. As of March 31, 2020 and December 31, 2019, accounts payable – due to affiliates included $2 million and $11 million, respectively, of liabilities attributable to Liability Awards.

As of March 31, 2020, there was $97 million of unrecognized stock-based compensation expense related to unvested share-based compensation plans, including $10 million attributable to stock-based awards that are expected to be settled on their vesting date in cash, rather than in equity shares. The unrecognized compensation expense will be recognized on a straight-line basis over the remaining vesting periods of the awards, which is a period of less than three years on a weighted average basis.

Activity for outstanding restricted stock awards, performance units and stock options is as follows:

	Three Months Ended March 31, 2020
	Restricted Stock Equity Awards	Restricted Stock Liability Awards	Performance Units	Stock Options
Beginning incentive compensation awards	824,193	246,851	116,215	121,953
Awards granted	64,805	3,061	132,621	—
Awards forfeited	(6,219)	(2,568)	—	—
Awards vested (a)	(217,947)	(67,927)	—	—
Options exercised	—	—	—	(7,728)
Ending incentive compensation awards	664,832	179,417	248,836	114,225

______________________

(a)Per the terms of award agreements and elections, the issuance of common stock may be deferred for certain restricted stock equity awards, performance units and stock options that vest during the period.

XML

Subsequent Events	3 Months Ended
	Mar. 31, 2020
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events

XML

Derivative Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of oil derivative contracts volume and weighted average price

Volumes per day associated with the Company's outstanding oil derivative contracts as of March 31, 2020 and the weighted average oil prices for those contracts are as follows:

	2020						Year Ending December 31, 2021
	Second Quarter		Third Quarter		Fourth Quarter
Brent collar contracts with short puts: (a)
Volume per day (Bbl)	135,500		115,500		115,500		—
Price per Bbl:
Ceiling	$	68.84	$	69.78	$	69.78	$	—
Floor	$	61.76	$	62.06	$	62.06	$	—
Short put	$	53.48	$	53.56	$	53.56	$	—
Brent swap contracts:
Volume per day (Bbl)	98,911		177,900		160,900		57,750
Price per Bbl	$	37.27	35.68		$	36.43	$	43.29
Brent call contracts sold:
Volume per day (Bbl) (b)	—		—		—		20,000
Price per Bbl	$	—	$	—	$	—	$	69.74
Brent collar contracts with short puts:
Volume per day (Bbl)	120,000		30,000		30,000		96,000
Price per Bbl:
Ceiling	$	36.53	$	43.09	$	43.09	$	47.07
Floor	$	31.08	$	34.83	$	34.83	$	42.50
Short put	$	21.28	$	24.83	$	24.83	$	31.45

______________________

(a)Represents collar contracts with short puts that were entered into prior to March 2020. During March 2020, the Company entered into incremental swap contracts and collar contracts with short puts to provide additional downside price protection for the second quarter through fourth quarter 2020 volumes.

(b)The referenced call contracts were sold in exchange for higher ceiling prices on certain 2020 collar contracts with short puts.

See Note 17 for changes in the Company's derivative contracts subsequent to March 31, 2020.

Schedule of gas derivative volume and weighted average prices

Volumes per day associated with outstanding gas derivative contracts as of March 31, 2020 and the weighted average gas prices for those contracts are as follows: 

	2020						Year Ending December 31, 2021
	Second Quarter		Third Quarter		Fourth Quarter
Swap contracts:
Volume per day (MMBtu)	30,000		30,000		16,739		2,466
Price per MMBtu	$	2.41	$	2.41	$	2.43	$	2.46
Basis swap contracts:
Permian Basin index swap volume per day(MMBtu) (a)	30,000		30,000		16,739		2,466
Price differential ($/MMBtu)	$	(1.68)	$	(1.68)	$	(1.59)	$	(1.46)

______________________

(a)The referenced basis swap contracts fix the basis differentials between the index price at which the Company sells its Permian Basin gas and the NYMEX index prices used in swap contracts.

Offsetting asset and liability

The fair value of derivative financial instruments not designated as hedging instruments is as follows:

As of March 31, 2020
Type	Consolidated Balance Sheet Location	Fair Value		Gross Amounts Offset in the Consolidated Balance Sheet		Net Fair Value Presented in the Consolidated Balance Sheet
		(in millions)
Assets:
Commodity price derivatives	Derivatives - current	$	386	$	—	$	386
Commodity price derivatives	Derivatives - noncurrent	$	43	$	—	$	43
Contingent consideration	Other assets - noncurrent	$	28	$	—	$	28
Liabilities:
Commodity price derivatives	Derivatives - current	$	3	$	—	$	3
Commodity price derivatives	Derivatives - noncurrent	$	3	$	—	$	3

As of December 31, 2019
Type	Consolidated Balance Sheet Location	Fair Value		Gross Amounts Offset in the Consolidated Balance Sheet		Net Fair Value Presented in the Consolidated Balance Sheet
		(in millions)
Assets:
Commodity price derivatives	Derivatives - current	$	32	$	—	$	32
Contingent consideration	Other assets - noncurrent	$	91	$	—	$	91
Liabilities:
Commodity price derivatives	Derivatives - current	$	12	$	—	$	12
Commodity price derivatives	Derivatives - noncurrent	$	8	$	—	$	8

Schedule of derivative gains and losses recognized on statement of operations

Gains and losses on derivative contracts are as follows:

Derivatives Not Designated  as Hedging Instruments	Location of Gain (Loss) Recognized in Earnings on Derivatives	Three Months Ended March 31,
		2020		2019
		(in millions)
Commodity price derivatives	Derivative gain (loss), net	$	475	$	(13)
Contingent consideration	Interest and other income (loss), net	$	(63)	$	—
Interest rate derivatives	Derivative gain (loss), net	$	(22)	$	—

XML

Income Taxes (Schedule of Income Tax Provision and Effective Tax Rate) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Income Tax Disclosure [Abstract]
Deferred tax provision	$ (76)	$ (103)
Effective tax rate	21.00%	23.00%

XML

Net Income Per Share (Schedule of Weighted Average Number of Shares) (Details) - shares shares in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Earnings Per Share [Abstract]
Basic and diluted weighted average shares outstanding	166	169

XML

Derivative Financial Instruments (Schedule of Gas Derivative Contracts Volume and Weighted Average Prices) (Details) $ in Millions	Mar. 31, 2020 MMBTU / d $ / MMBTU	May 31, 2019 USD ($)
South Texas Divestiture
Derivative [Line Items]
Contingent consideration | $		$ 136
South Texas Divestiture | Maximum
Derivative [Line Items]
Contingent consideration | $		$ 450
Swap contracts, Second Quarter | Gas contracts, in MMBTU
Derivative [Line Items]
Volume, barrels per day | MMBTU / d	30,000
Swap contracts, Second Quarter | Gas contracts, price per MMBTU
Derivative [Line Items]
Price per MMBtu in usd | $ / MMBTU	2.41
Swap contracts, Third Quarter | Gas contracts, in MMBTU
Derivative [Line Items]
Volume, barrels per day | MMBTU / d	30,000
Swap contracts, Third Quarter | Gas contracts, price per MMBTU
Derivative [Line Items]
Price per MMBtu in usd | $ / MMBTU	2.41
Swap contracts, Fourth Quarter | Gas contracts, in MMBTU
Derivative [Line Items]
Volume, barrels per day | MMBTU / d	16,739
Swap contracts, Fourth Quarter | Gas contracts, price per MMBTU
Derivative [Line Items]
Price per MMBtu in usd | $ / MMBTU	2.43
Swap Contracts For Year Two | Gas contracts, in MMBTU
Derivative [Line Items]
Volume, barrels per day | MMBTU / d	2,466
Swap Contracts For Year Two | Gas contracts, price per MMBTU
Derivative [Line Items]
Price per MMBtu in usd | $ / MMBTU	2.46
Basis swap contracts, Second Quarter | Gas contracts, in MMBTU | Permian Basin
Derivative [Line Items]
Volume, barrels per day | MMBTU / d	30,000
Basis swap contracts, Second Quarter | Gas contracts, price per MMBTU | Permian Basin
Derivative [Line Items]
Price differential, dollars per barrel | $ / MMBTU	(1.68)
Basis swap contracts, Third Quarter | Gas contracts, in MMBTU | Permian Basin
Derivative [Line Items]
Volume, barrels per day | MMBTU / d	30,000
Basis swap contracts, Third Quarter | Gas contracts, price per MMBTU | Permian Basin
Derivative [Line Items]
Price differential, dollars per barrel | $ / MMBTU	(1.68)
Basis swap contracts, Fourth Quarter | Gas contracts, in MMBTU | Permian Basin
Derivative [Line Items]
Volume, barrels per day | MMBTU / d	16,739
Basis swap contracts, Fourth Quarter | Gas contracts, price per MMBTU | Permian Basin
Derivative [Line Items]
Price differential, dollars per barrel | $ / MMBTU	(1.59)
Basis Swap Contracts for Year Two | Gas contracts, in MMBTU | Permian Basin
Derivative [Line Items]
Volume, barrels per day | MMBTU / d	2,466
Basis Swap Contracts for Year Two | Gas contracts, price per MMBTU | Permian Basin
Derivative [Line Items]
Price differential, dollars per barrel | $ / MMBTU	(1.46)

XML

Fair Value Measurements (Measured On A Nonrecurring Basis) (Details) - Management's Price Outlooks	3 Months Ended
	Mar. 31, 2020 $ / bbl $ / MMBTU
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Management oil price outlook (usd per BBL) | $ / bbl	42.84
Management gas price outlook (usd per million BTU) | $ / MMBTU	2.49

XML

Incentive Plans (Schedule of Stock-based Compensation Expense) (Details) - USD ($)	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 16,000,000	$ 29,000,000
Due to affiliates	100,000,000		$ 190,000,000
Unrecognized stock-based compensation expense	$ 97,000,000
Remaining vesting period awards (less than)	3 years
Restricted stock - Equity Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 11,000,000	18,000,000
Restricted Stock Liability Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	0	5,000,000
Unrecognized stock-based compensation expense	10,000,000
Restricted Stock Liability Awards | Affiliates
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Due to affiliates	2,000,000		$ 11,000,000
Performance unit awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	4,000,000	5,000,000
Employee stock purchase plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 1,000,000	$ 1,000,000

XML

Commitments and Contingencies (Schedule of Changes in Contract Obligations) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	May 31, 2019
Loss Contingency Accrual [Roll Forward]
Beginning contract obligations	$ 468
Liabilities settled	(152)
Accretion of discount	3
Changes in estimate	66
Ending contract obligations	385
South Texas Divestiture
Loss Contingency Accrual [Roll Forward]
Deficiency fee liability		$ 348
South Texas Divestiture
Loss Contingency Accrual [Roll Forward]
Deficiency fee liability	$ (323)

XML

Interest and Other Income (Loss), Net (Components of Interest and Other Income) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Interest and Other Income [Abstract]
Interest income	$ 2	$ 8
Investment in affiliate mark-to-market adjustment (Note 4)	145	(174)
Contingent consideration valuation adjustment	(63)	0
Deferred compensation plan income (loss)	(3)	7
Other	3	2
Interest and other income (loss), net	$ (206)	$ 191

XML

Exploratory Costs

3 Months Ended

Mar. 31, 2020

Extractive Industries [Abstract]

Exploratory Costs

Exploratory CostsThe Company capitalizes exploratory well and project costs until a determination is made that the well or project has either found proved reserves, is impaired or is sold. The Company's capitalized exploratory well and project costs are included in proved properties in the consolidated balance sheets. If the exploratory well or project is determined to be impaired, the impaired costs are charged to exploration and abandonments expense.

The changes in capitalized exploratory well costs are as follows:

	Three Months Ended March 31, 2020
	(in millions)
Beginning capitalized exploratory well costs	$	660
Additions to exploratory well costs pending the determination of proved reserves	526
Reclassification due to determination of proved reserves	(577)
Ending capitalized exploratory well costs	$	609

The Company has no wells or projects with exploratory well costs that have been suspended for a period of greater than one year.

XML

Commitments and Contingencies

3 Months Ended

Mar. 31, 2020

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Legal actions. The Company is a party to various proceedings and claims incidental to its business. While many of these matters involve inherent uncertainty, the Company believes that the amount of the liability, if any, ultimately incurred with respect to these proceedings and claims will not have a material adverse effect on the Company's consolidated financial position as a whole or on its liquidity, capital resources or future annual results of operations. The Company records reserves for contingencies when information available indicates that a loss is probable and the amount of the loss can be reasonably estimated.

Indemnifications. The Company has agreed to indemnify its directors and certain of its officers, employees and agents with respect to claims and damages arising from acts or omissions taken in such capacity, as well as with respect to certain litigation.

Environmental. Environmental expenditures that relate to an existing condition caused by past operations and that have no future economic benefits are expensed. Environmental expenditures that extend the life of the related property or mitigate or prevent future environmental contamination are capitalized. Liabilities for expenditures that will not qualify for capitalization are recorded when environmental assessment and/or remediation is probable and the costs can be reasonably estimated. Such

liabilities are undiscounted unless the timing of cash payments for the liability is fixed or reliably determinable. Environmental liabilities normally involve estimates that are subject to revision until settlement or remediation occurs.

Firm purchase, gathering, processing, transportation, fractionation and storage commitments. From time to time, the Company enters into, and as of March 31, 2020 was a party to, take-or-pay agreements, which include contractual commitments (i) to purchase sand and water for use in the Company's drilling operations, (ii) with midstream service companies and pipeline carriers for future gathering, processing, transportation, fractionation and storage and (iii) with oilfield services companies that provide drilling and pressure pumping services. These commitments are normal and customary for the Company's business activities.

Obligations following divestitures. In connection with its divestiture transactions, the Company may retain certain liabilities and provide the purchaser certain indemnifications, subject to defined limitations, which may apply to identified pre-closing matters, including matters of litigation, environmental contingencies, royalty and income taxes. Also associated with its divestiture transactions, the Company has issued and received guarantees to facilitate the transfer of contractual obligations, such as firm transportation agreements or gathering and processing arrangements. The Company does not recognize a liability if the fair value of the obligation is immaterial and the likelihood of making payments under these guarantees is remote.

South Texas Divestiture. In conjunction with the South Texas Divestiture, the Company transferred its long-term midstream agreements and associated MVC's to the buyer. However, the Company retained the obligation to pay 100 percent of any deficiency fees associated with the MVC's from January 2019 through July 2022. The buyer is required to reimburse the Company for 18 percent of the deficiency fees paid by the Company from January 2019 through July 2022; such reimbursement will be paid by the buyer in installments beginning in years 2023 through 2025. Assuming 100 percent of the MVC's are paid as deficiency fees, the maximum amount of future payments for this obligation would be approximately $471 million as of March 31, 2020. The Company's estimated deficiency fee obligation as of March 31, 2020 is $323 million, of which $130 million is included in other current liabilities in the consolidated balance sheets. The deficiency fee receivable from the buyer of $70 million is included in noncurrent other assets in the consolidated balance sheets. The Company has received credit support for the deficiency fee receivable and the contingent consideration of up to $325 million.

Raton transportation commitments. In July 2018, the Company completed the sale of its gas field assets in the Raton Basin to an unaffiliated third party and transferred certain gas transportation commitments, which extend through 2032, to the buyer for which the Company has provided a guarantee. Assuming 100 percent of the remaining commitments are paid by the Company under its guarantee, the maximum amount of future payments would be approximately $90 million as of March 31, 2020. The Company has received credit support for the commitments of up to $50 million. The Company paid $3 million in gas transportation fees associated with the transferred commitment for the three months ended March 31, 2020 and was fully reimbursed.

Certain contractual obligations were retained by the Company after the South Texas Divestiture, the divestiture of the Company's gas field assets in the Raton Basin, the divestiture of the Company's pressure pumping assets and the decommissioning of the Company's sand mine operations in Brady, Texas. These contracts were primarily related to firm transportation and storage agreements in which the Company is unlikely to realize any benefit. The estimated obligations associated with these agreements are included in other current or noncurrent liabilities in the consolidated balance sheets.

The changes in contract obligations are as follows:

	Three Months Ended March 31, 2020
	(in millions)
Beginning contract obligations	$	468
Liabilities settled	(152)
Accretion of discount	3
Changes in estimate (a)	66
Ending contract obligations	$	385

______________________

(a)Represents changes in the Company's forecasted deficiency fee payments associated with the South Texas Divestiture and the difference between estimated and actual liabilities settled.

XML

Organization and Nature of Operations (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from disposition of assets, net of cash sold	$ 1	$ 6

XML

Consolidated Statements of Equity (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Statement of Stockholders' Equity [Abstract]
Dividends declared (usd per share)	$ 0.55	$ 0.32

XML

Interest and Other Income (Loss), Net (Tables)

3 Months Ended

Mar. 31, 2020

Interest and Other Income [Abstract]

Components of interest and other income (loss), net

The components of net interest and other income (loss) are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Interest income	$	2	$	8
Investment in affiliate valuation adjustment (Note 4)	(145)		174
Contingent consideration valuation adjustment (Note 4)	(63)		—
Deferred compensation plan income (loss)	(3)		7
Other	3		2
	$	(206)	$	191

XML

Asset Retirement Obligations (Tables)

3 Months Ended

Mar. 31, 2020

Asset Retirement Obligation [Abstract]

Schedule of asset retirement obligations

The changes in asset retirement obligations are as follows: 

	Three Months Ended March 31, 2020
	(in millions)
Beginning asset retirement obligations	$	191
New wells placed on production	1
Changes in estimates (a)	(5)
Liabilities settled	(16)
Accretion of discount	2
Ending asset retirement obligations	173
Less current portion of asset retirement obligations	(16)
Asset retirement obligations - noncurrent	$	157

______________________

(a)Changes in estimates are determined based on several factors, including abandonment cost estimates based on recent actual costs incurred to abandon wells, credit-adjusted risk-free discount rates, economic well life estimates and forecasted timing of abandoning wells.

XML

Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 784	$ 631
Restricted cash	74	74
Accounts receivable:
Trade, net	555	1,032
Due from affiliates	0	3
Income taxes receivable	9	7
Inventories	188	205
Derivatives	386	32
Investment in affiliate	42	187
Other	31	20
Total current assets	2,069	2,191
Oil and gas properties, using the successful efforts method of accounting:
Proved properties	23,029	22,444
Unproved properties	583	584
Accumulated depletion, depreciation and amortization	(8,987)	(8,583)
Total oil and gas properties, net	14,625	14,445
Other property and equipment, net	1,629	1,632
Operating lease right-of-use assets	250	280
Goodwill	261	261
Derivatives	43	0
Other assets	174	258
Total Assets	19,051	19,067
Accounts payable:
Trade	973	1,221
Due to affiliates	100	190
Interest payable	18	53
Income taxes payable	3	3
Current portion of long-term debt	499	450
Derivatives	3	12
Operating leases	128	136
Other	356	431
Total current liabilities	2,080	2,496
Long-term debt	2,140	1,839
Derivatives	3	8
Deferred income taxes	1,465	1,389
Operating leases	146	170
Other liabilities	1,006	1,046
Equity:
Common stock, $0.01 par value; 500,000,000 shares authorized; 175,373,639 and 175,057,889 shares issued as of March 31, 2020 and December 31, 2019, respectively	2	2
Additional paid-in capital	9,176	9,161
Treasury stock at cost: 10,510,424 and 9,511,248 shares as of March 31, 2020 and December 31, 2019, respectively	(1,190)	(1,069)
Retained earnings	4,223	4,025
Total equity	12,211	12,119
Commitments and contingencies
Total Liabilities and Equity	$ 19,051	$ 19,067

XML

Other Expense

3 Months Ended

Mar. 31, 2020

Other Income and Expenses [Abstract]

Other Expense

Other Expense

The components of other expense are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
South Texas deficiency fee obligation (Note 4)	$	69	$	—
Termination and idle drilling and frac equipment charges (a)	8		4
Transportation commitment charges (b)	4		40
Legal and environmental charges	3		5
Restructuring charges (Note 3)	—		13
Asset impairment (Note 4)	—		28
Sand mine decommissioning-related charges (Note 3)	—		23
Vertical integration services (income) loss, net (c)	(4)		20
Other	5		14
	$	85	$	147

____________________

(a)Includes idle frac fleet fees, stacked drilling rig charges and drilling rig early termination charges.

(b)Primarily represents firm transportation payments on excess pipeline capacity commitments.

(c)For the three months ended March 31, 2019, amount includes $9 million of decommissioning operating expenses related to the Company's Brady sand mine and $15 million of carryover and winding down operating expenses related to the Company's sale of its pressure pumping services assets in December 2018. The components of the vertical integration services net margins are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Gross revenues	$	11	$	35
Gross costs and expenses	$	7	$	55

XML

Divestitures, Decommissioning and Restructuring Activities (Tables)

3 Months Ended

Mar. 31, 2020

Discontinued Operations and Disposal Groups [Abstract]

Schedule of divestiture-related charges

The changes in the Company's total employee-related obligations are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Beginning employee-related obligations	$	6	$	27
Additions (Note 14)	—		13
Cash payments	(5)		(10)
Noncash changes	—		(4)
Ending employee-related obligations	$	1	$	26

XML

Incentive Plans (Tables)

3 Months Ended

Mar. 31, 2020

Compensation Related Costs [Abstract]

Schedule of stock-based compensation expense

Stock-based compensation expense is as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Restricted stock - Equity Awards	$	11	$	18
Restricted stock - Liability Awards (a)	—		5
Performance unit awards	4		5
Employee stock purchase plan	1		1
	$	16	$	29

______________________

(a)Liability Awards are expected to be settled on their vesting date in cash. As of March 31, 2020 and December 31, 2019, accounts payable – due to affiliates included $2 million and $11 million, respectively, of liabilities attributable to Liability Awards.

Schedule of share based incentive award activity

Activity for outstanding restricted stock awards, performance units and stock options is as follows:

	Three Months Ended March 31, 2020
	Restricted Stock Equity Awards	Restricted Stock Liability Awards	Performance Units	Stock Options
Beginning incentive compensation awards	824,193	246,851	116,215	121,953
Awards granted	64,805	3,061	132,621	—
Awards forfeited	(6,219)	(2,568)	—	—
Awards vested (a)	(217,947)	(67,927)	—	—
Options exercised	—	—	—	(7,728)
Ending incentive compensation awards	664,832	179,417	248,836	114,225

______________________

(a)Per the terms of award agreements and elections, the issuance of common stock may be deferred for certain restricted stock equity awards, performance units and stock options that vest during the period.

XML

Derivative Financial Instruments (Schedule of Derivative Obligations Under Terminated Hedge Arrangements) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Derivative [Line Items]
Derivative gain (loss), net	$ 453	$ (13)
Derivative gain (loss), net | Commodity price derivatives
Derivative [Line Items]
Derivative gain (loss), net	475	$ (13)
Derivative gain (loss), net | Interest rate derivatives
Derivative [Line Items]
Derivative gain (loss), net	$ (22)

XML

Fair Value Measurements (Schedule of Carrying Values and Financial Instruments Not Carried at Fair Value) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019	Mar. 31, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	$ 784	$ 631
(in millions)	74	74
Current portion of long-term debt	499	450
Long-term debt	2,140	1,839
Line of Credit
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	796	0
Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	1,344	1,839
Estimate of Fair Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Current portion of long-term debt	500		$ 451
Long-term debt	2,194	1,995
Estimate of Fair Value Measurement [Member] | Line of Credit
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	797	0
Estimate of Fair Value Measurement [Member] | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	1,397	1,995
Cash
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	784	631
Cash and cash equivalents, Fair Value	$ 784	$ 631

XML

Divestitures, Decommissioning and Restructuring Activities (Schedule of Restructuring and Employee Related Costs) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Restructuring Reserve [Roll Forward]
Additions (Note 14)	$ 0	$ 13
Employee severance
Restructuring Reserve [Roll Forward]
Beginning employee-related obligations	6	27
Additions (Note 14)	0	13
Cash payments	(5)	(10)
Noncash changes	0	(4)
Ending employee-related obligations	$ 1	$ 26

XML

Income Taxes (Schedule of Unrecognized Tax Benefits) (Details) $ in Millions	Mar. 31, 2020 USD ($)
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Unrecognized Tax Benefits, Beginning Balance	$ 39

XML

Subsequent Events (Details)		1 Months Ended
	Apr. 20, 2020 $ / bbl	Apr. 30, 2020 USD ($)	May 07, 2020 bbl / d MMBTU / d $ / MMBTU $ / bbl	Apr. 03, 2020 USD ($)	Mar. 31, 2020 USD ($) bbl / d MMBTU / d $ / MMBTU
Subsequent Event [Line Items]
Aggregate loan commitments | $					$ 1,500,000,000
Brent swap contracts, Next Year | Oil contracts
Subsequent Event [Line Items]
Volume, barrels per day | bbl / d					57,750
Brent swap contracts, Next Year | Oil contracts, price per bbl
Subsequent Event [Line Items]
Price per Bbl in usd					43.29
Certain Brent Swap Contracts [Member] | Oil contracts
Subsequent Event [Line Items]
Volume, barrels per day | bbl / d					19,000
Certain Brent Swap Contracts [Member] | Oil contracts, price per bbl
Subsequent Event [Line Items]
Price per Bbl in usd					39.97
Swap contracts, Second Quarter | Gas contracts, in MMBTU
Subsequent Event [Line Items]
Volume, barrels per day | MMBTU / d					30,000
Subsequent event | Wells Fargo Bank, National Association
Subsequent Event [Line Items]
Aggregate loan commitments | $				$ 905,000,000
Subsequent event | WTI
Subsequent Event [Line Items]
Sale price per barrel | $ / bbl	37.63
Subsequent event | West Texas Intermediate Swaps for the Second Quarter of Year One | Oil contracts
Subsequent Event [Line Items]
Volume, barrels per day | bbl / d			42,033
Subsequent event | West Texas Intermediate Swaps for the Second Quarter of Year One | Oil contracts, price per bbl
Subsequent Event [Line Items]
Price per Bbl in usd			21.50
Subsequent event | West Texas Intermediate Swaps for Third Quarter of Year One | Oil contracts
Subsequent Event [Line Items]
Volume, barrels per day | bbl / d			0
Subsequent event | West Texas Intermediate Swaps for Third Quarter of Year One | Oil contracts, price per bbl
Subsequent Event [Line Items]
Price per Bbl in usd			0
Subsequent event | West Texas Intermediate Swaps for Fourth Quarter of Year One | Oil contracts
Subsequent Event [Line Items]
Volume, barrels per day | bbl / d			0
Subsequent event | West Texas Intermediate Swaps for Fourth Quarter of Year One | Oil contracts, price per bbl
Subsequent Event [Line Items]
Price per Bbl in usd			0
Subsequent event | West Texas Intermediate Swaps for Year Two | Oil contracts
Subsequent Event [Line Items]
Volume, barrels per day | bbl / d			0
Subsequent event | West Texas Intermediate Swaps for Year Two | Oil contracts, price per bbl
Subsequent Event [Line Items]
Price per Bbl in usd			0
Subsequent event | Permian collar contracts for the Second Quarter of Year One [Member] | Gas contracts, in MMBTU
Subsequent Event [Line Items]
Volume, barrels per day | MMBTU / d			0
Ceiling, price per barrel | $ / bbl			0
Short put, price per barrel			0
Subsequent event | Permian collar contracts for the Third Quarter of Year One [Member] | Gas contracts, in MMBTU
Subsequent Event [Line Items]
Volume, barrels per day | MMBTU / d			0
Ceiling, price per barrel | $ / bbl			0
Short put, price per barrel			0
Subsequent event | Permian collar contracts for the Fourth Quarter of Year One [Member] | Gas contracts, in MMBTU
Subsequent Event [Line Items]
Volume, barrels per day | MMBTU / d			0
Ceiling, price per barrel | $ / bbl			0
Short put, price per barrel			0
Subsequent event | Permian collar contracts for Year Two [Member] | Gas contracts, in MMBTU
Subsequent Event [Line Items]
Volume, barrels per day | MMBTU / d			80,000
Ceiling, price per barrel | $ / bbl			3.15
Short put, price per barrel			2.50
Subsequent event | Certain Brent Swap Contracts [Member] | Oil contracts, price per bbl
Subsequent Event [Line Items]
Gain contract unwinding | $		$ 9,000,000

XML

Exploratory Costs (Tables)

3 Months Ended

Mar. 31, 2020

Extractive Industries [Abstract]

Capitalized exploratory well and project activity

The changes in capitalized exploratory well costs are as follows:

	Three Months Ended March 31, 2020
	(in millions)
Beginning capitalized exploratory well costs	$	660
Additions to exploratory well costs pending the determination of proved reserves	526
Reclassification due to determination of proved reserves	(577)
Ending capitalized exploratory well costs	$	609

XML

Interest and Other Income (Loss), Net

3 Months Ended

Mar. 31, 2020

Interest and Other Income [Abstract]

Interest and Other Income (Loss), Net

Interest and Other Income (Loss), Net

The components of net interest and other income (loss) are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Interest income	$	2	$	8
Investment in affiliate valuation adjustment (Note 4)	(145)		174
Contingent consideration valuation adjustment (Note 4)	(63)		—
Deferred compensation plan income (loss)	(3)		7
Other	3		2
	$	(206)	$	191

XML

Basis of Presentation (Policies)

3 Months Ended

Mar. 31, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Presentation

Presentation. In the opinion of management, the unaudited interim consolidated financial statements of the Company as of March 31, 2020 and for the three months ended March 31, 2020 and 2019 include all adjustments and accruals, consisting only of normal, recurring adjustments and accruals necessary for a fair presentation of the results for the interim periods in conformity with generally accepted accounting principles in the United States ("GAAP"). The operating results for the three months ended March 31, 2020 are not necessarily indicative of results for a full year.

Certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted in accordance with the rules and regulations of the United States Securities and Exchange Commission (the "SEC"). These unaudited interim consolidated financial statements should be read together with the consolidated financial statements and notes thereto included in the Company's Annual Report on Form 10-K for the year ended December 31, 2019.

Adoption of new accounting standards and new accounting pronouncements

Adoption of new accounting standards. In June 2016, the FASB issued ASU 2016-13, "Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments" ("ASU 2016-13"). Effective January 1, 2020, the Company adopted ASU 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments prospectively. This ASU replaces the incurred loss impairment model with an expected credit loss impairment model for financial instruments, including trade receivables. The amendment requires entities to consider forward-looking information to estimate expected credit losses, resulting in earlier recognition of losses for receivables that are current or not yet due, which were not considered under the previous accounting guidance. The impact of the adoption of this ASU was not material.

The Company is exposed to credit losses primarily through sales of oil, NGLs, gas and purchased oil and gas. The Company’s expected loss allowance methodology for accounts receivable is developed using historical collection experience, current and future economic and market conditions and a review of the current status of customers' trade accounts receivables.

Due to the short-term nature of such receivables, the estimate of amount of accounts receivable that may not be collected is based on aging of the accounts receivable balances and the financial condition of customers. The Company’s monitoring activities include timely account reconciliation, dispute resolution, payment confirmation, consideration of customers' financial condition and macroeconomic conditions. Balances are written off when determined to be uncollectible. The Company considered the current and expected future economic and market conditions surrounding the COVID-19 pandemic and determined that the estimate of credit losses was not significantly impacted.

XML

Derivative Financial Instruments (Schedule of Oil Derivative Contracts Volume and Weighted Average Prices) (Details)	Mar. 31, 2020 bbl / d $ / bbl $ / MMBTU
Oil contracts | Brent swap contracts, Second Quarter
Derivative [Line Items]
Volume, barrels per day | bbl / d	98,911
Oil contracts | Brent swap contracts, Third Quarter
Derivative [Line Items]
Volume, barrels per day | bbl / d	177,900
Oil contracts | Brent swap contracts, Fourth Quarter
Derivative [Line Items]
Volume, barrels per day | bbl / d	160,900
Oil contracts | Brent swap contracts, Next Year
Derivative [Line Items]
Volume, barrels per day | bbl / d	57,750
Oil contracts | Brent collar contracts with short puts, Second Quarter
Derivative [Line Items]
Volume, barrels per day | bbl / d	120,000
Oil contracts | Brent Collar Contracts Entered in March With Short Puts for Second Quarter of Year One [Member]
Derivative [Line Items]
Volume, barrels per day | bbl / d	135,500
Ceiling, price per barrel	68.84
Floor, price per barrel	61.76
Short put, price per barrel	53.48
Oil contracts | Brent collar contracts with short puts, Third Quarter
Derivative [Line Items]
Volume, barrels per day | bbl / d	30,000
Oil contracts | Brent Collar Contracts entered in March With Short Puts for Third Quarter of Year One [Member]
Derivative [Line Items]
Volume, barrels per day | bbl / d	115,500
Ceiling, price per barrel	69.78
Floor, price per barrel	62.06
Short put, price per barrel	53.56
Oil contracts | Brent collar contracts with short puts, Fourth Quarter
Derivative [Line Items]
Volume, barrels per day | bbl / d	30,000
Oil contracts | Brent Collar Contracts Entered in March With Short Puts for Fourth Quarter of Year One [Member]
Derivative [Line Items]
Volume, barrels per day | bbl / d	115,500
Ceiling, price per barrel	69.78
Floor, price per barrel	62.06
Short put, price per barrel	53.56
Oil contracts | Brent collar contracts with short puts, Next Year
Derivative [Line Items]
Volume, barrels per day | bbl / d	96,000
Oil contracts | Brent Collar Contracts Entered in March With Short Puts for Year Two [Member]
Derivative [Line Items]
Volume, barrels per day | bbl / d	0
Ceiling, price per barrel	0
Floor, price per barrel	0
Short put, price per barrel	0
Oil contracts | Brent call contracts sold, Second Quarter
Derivative [Line Items]
Volume, barrels per day | bbl / d	0
Oil contracts | Brent call contracts sold, Third Quarter
Derivative [Line Items]
Volume, barrels per day | bbl / d	0
Oil contracts | Brent call contracts sold, Fourth Quarter
Derivative [Line Items]
Volume, barrels per day | bbl / d	0
Oil contracts | Brent call contracts sold, Next Year
Derivative [Line Items]
Volume, barrels per day | bbl / d	20,000
Oil contracts, price per bbl | Brent swap contracts, Second Quarter
Derivative [Line Items]
Price per Bbl in usd | $ / MMBTU	37.27
Oil contracts, price per bbl | Brent swap contracts, Third Quarter
Derivative [Line Items]
Price per Bbl in usd | $ / MMBTU	35.68
Oil contracts, price per bbl | Brent swap contracts, Fourth Quarter
Derivative [Line Items]
Price per Bbl in usd | $ / MMBTU	36.43
Oil contracts, price per bbl | Brent swap contracts, Next Year
Derivative [Line Items]
Price per Bbl in usd | $ / MMBTU	43.29
Oil contracts, price per bbl | Brent collar contracts with short puts, Second Quarter
Derivative [Line Items]
Ceiling, price per barrel	36.53
Floor, price per barrel	31.08
Short put, price per barrel	21.28
Oil contracts, price per bbl | Brent collar contracts with short puts, Third Quarter
Derivative [Line Items]
Ceiling, price per barrel	43.09
Floor, price per barrel	34.83
Short put, price per barrel	24.83
Oil contracts, price per bbl | Brent collar contracts with short puts, Fourth Quarter
Derivative [Line Items]
Ceiling, price per barrel	43.09
Floor, price per barrel	34.83
Short put, price per barrel	24.83
Oil contracts, price per bbl | Brent collar contracts with short puts, Next Year
Derivative [Line Items]
Ceiling, price per barrel	47.07
Floor, price per barrel	42.50
Short put, price per barrel	31.45
Oil contracts, price per bbl | Brent call contracts sold, Second Quarter
Derivative [Line Items]
Price per Bbl in usd | $ / MMBTU	0
Oil contracts, price per bbl | Brent call contracts sold, Third Quarter
Derivative [Line Items]
Price per Bbl in usd | $ / MMBTU	0
Oil contracts, price per bbl | Brent call contracts sold, Fourth Quarter
Derivative [Line Items]
Price per Bbl in usd | $ / MMBTU	0
Oil contracts, price per bbl | Brent call contracts sold, Next Year
Derivative [Line Items]
Price per Bbl in usd | $ / MMBTU	69.74

XML

Fair Value Measurements (Schedule of Assets and Liabilities Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Assets:
Deferred compensation plan assets	$ 64	$ 85
Investment in affiliate	42	187
Contingent consideration	28	91
Total assets	563	395
Liabilities:
Total recurring fair value measurements	557	375
Investment in affiliate	42	187
Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Deferred compensation plan assets	64	85
Investment in affiliate	42	187
Contingent consideration	0	0
Total assets	106	272
Liabilities:
Total recurring fair value measurements	106	272
Investment in affiliate	42	187
Significant Other Observable Inputs (Level 2)
Assets:
Deferred compensation plan assets	0	0
Investment in affiliate	0	0
Contingent consideration	28	91
Total assets	457	123
Liabilities:
Total recurring fair value measurements	451	103
Investment in affiliate	0	0
Significant Unobservable Inputs (Level 3)
Assets:
Deferred compensation plan assets	0	0
Investment in affiliate	0	0
Contingent consideration	0	0
Total assets	0	0
Liabilities:
Total recurring fair value measurements	0	0
Investment in affiliate	0	0
Commodity price derivatives
Assets:
Commodity price derivatives	429	32
Liabilities:
Commodity price derivatives	6	20
Commodity price derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Commodity price derivatives	0	0
Liabilities:
Commodity price derivatives	0	0
Commodity price derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Commodity price derivatives	429	32
Liabilities:
Commodity price derivatives	6	20
Commodity price derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Commodity price derivatives	0	0
Liabilities:
Commodity price derivatives	$ 0	$ 0

XML

Exploratory Costs (Schedule of Capitalized Exploratory Well and Project Activity) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2020 USD ($)
Increase (Decrease) in Capitalized Exploratory Well Costs that are Pending Determination of Proved Reserves [Roll Forward]
Beginning capitalized exploratory well costs	$ 660
Additions to exploratory well costs pending the determination of proved reserves	526
Reclassification due to determination of proved reserves	(577)
Ending capitalized exploratory well costs	$ 609

XML

Income Taxes (Narrative) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Unrecognized tax benefits	$ 39	$ 39

XML

Net Income Per Share (Narrative) (Details) - Common stock repurchase program - USD ($)	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Dec. 13, 2018
Equity, Class of Treasury Stock [Line Items]
Authorized amount			$ 2,000,000,000
Remaining authorized amount	$ 1,100,000,000
Purchases of treasury stock (shares)	110,000,000	200,000,000
Stock Repurchased During Period, Shares	919,794	1,436,533

XML

Revenue Recognition (Narrative) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
Accounts receivable balance representing amounts due or billable	$ 462	$ 968

XML

Long-term Debt (Details) - USD ($) $ in Millions	Jan. 01, 2020	May 07, 2020	Mar. 31, 2020
Debt Instrument [Line Items]
Aggregate loan commitments			$ 1,500.0
Outstanding borrowing			800.0
Unused borrowing capacity			$ 700.0
Line of Credit
Debt Instrument [Line Items]
Aggregate loan commitments		$ 905.0
7.50% Senior notes due 2020
Debt Instrument [Line Items]
Stated interest rate	7.50%
Repaid principal balance	$ 450.0
3.45% Senior Notes due 2021
Debt Instrument [Line Items]
Stated interest rate			3.45%
Principal balance			$ 500.0
Commitment
Debt Instrument [Line Items]
Unused borrowing capacity			$ 3.7

XML

Commitments and Contingencies (Narrative) (Details) - USD ($) $ in Millions		3 Months Ended	42 Months Ended	180 Months Ended
	Jun. 30, 2019	Mar. 31, 2020	Jul. 01, 2022	Dec. 31, 2032	May 31, 2019
South Texas Divestiture
Loss Contingencies [Line Items]
Deficiency fee liability		$ (323)
Receivable from buyer		70
Credit support from third parties		325
South Texas Divestiture | Maximum
Loss Contingencies [Line Items]
Retained obligation percentage	100.00%
Deficiency fee liability		471
South Texas Divestiture | Forecast
Loss Contingencies [Line Items]
Retained obligation percentage			100.00%
South Texas Divestiture | Forecast | Maximum
Loss Contingencies [Line Items]
Retained obligation percentage			100.00%
Buyer recovery percentage			18.00%
Raton transportation commitments
Loss Contingencies [Line Items]
Credit support from third parties		50
Deficiency Fees Paid and Reimbursed		3
Raton transportation commitments | Maximum
Loss Contingencies [Line Items]
Deficiency fee liability		90
Raton transportation commitments | Forecast | Maximum
Loss Contingencies [Line Items]
Retained obligation percentage				100.00%
South Texas Divestiture
Loss Contingencies [Line Items]
Deficiency fee liability					$ 348
South Texas Divestiture | South Texas Divestiture
Loss Contingencies [Line Items]
Receivable from buyer					$ 72
South Texas Divestiture | Other current liabilities | South Texas Divestiture
Loss Contingencies [Line Items]
Monetary sanctions		$ 130

XML

Derivative Financial Instruments

3 Months Ended

Mar. 31, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Financial Instruments

Derivative Financial Instruments

The Company primarily utilizes commodity swap contracts, collar contracts, collar contracts with short puts and basis swap contracts to (i) reduce the effect of price volatility on the commodities the Company produces and sells or consumes, (ii) support the Company's annual capital budgeting and expenditure plans and (iii) reduce commodity price risk associated with certain capital projects. The Company also, from time to time, utilizes interest rate contracts to reduce the effect of interest rate volatility on the Company's indebtedness.

Oil production derivatives. The Company sells its oil production at the lease and the sales contracts governing such oil production are tied directly to, or are highly correlated with, New York Mercantile Exchange ("NYMEX") West Texas Intermediate ("WTI") oil prices. The Company also enters into pipeline capacity commitments in order to secure available oil, NGL and gas transportation capacity from its areas of production. To diversify the oil prices it receives, the Company enters into third party purchase transactions in its area of production and separate third party transactions for the sales of such purchased oil to Gulf Coast refineries or international export markets at prices that are highly correlated to Brent oil prices. As a result, the Company will generally use Brent derivative contracts to manage future oil price volatility.

Volumes per day associated with the Company's outstanding oil derivative contracts as of March 31, 2020 and the weighted average oil prices for those contracts are as follows:

	2020						Year Ending December 31, 2021
	Second Quarter		Third Quarter		Fourth Quarter
Brent collar contracts with short puts: (a)
Volume per day (Bbl)	135,500		115,500		115,500		—
Price per Bbl:
Ceiling	$	68.84	$	69.78	$	69.78	$	—
Floor	$	61.76	$	62.06	$	62.06	$	—
Short put	$	53.48	$	53.56	$	53.56	$	—
Brent swap contracts:
Volume per day (Bbl)	98,911		177,900		160,900		57,750
Price per Bbl	$	37.27	35.68		$	36.43	$	43.29
Brent call contracts sold:
Volume per day (Bbl) (b)	—		—		—		20,000
Price per Bbl	$	—	$	—	$	—	$	69.74
Brent collar contracts with short puts:
Volume per day (Bbl)	120,000		30,000		30,000		96,000
Price per Bbl:
Ceiling	$	36.53	$	43.09	$	43.09	$	47.07
Floor	$	31.08	$	34.83	$	34.83	$	42.50
Short put	$	21.28	$	24.83	$	24.83	$	31.45

______________________

(a)Represents collar contracts with short puts that were entered into prior to March 2020. During March 2020, the Company entered into incremental swap contracts and collar contracts with short puts to provide additional downside price protection for the second quarter through fourth quarter 2020 volumes.

(b)The referenced call contracts were sold in exchange for higher ceiling prices on certain 2020 collar contracts with short puts.

See Note 17 for changes in the Company's derivative contracts subsequent to March 31, 2020.

NGL production derivatives. All material physical sales contracts governing the Company's NGL production are tied directly or indirectly to Mont Belvieu, Texas NGL component product prices. The Company uses derivative contracts to manage the volatility of NGL component product prices. As of March 31, 2020, the Company did not have any NGL derivative contracts outstanding.

Gas production derivatives. All material physical sales contracts governing the Company's gas production are tied directly or indirectly to NYMEX Henry Hub ("HH") gas prices or regional index prices where the gas is sold. The Company uses derivative contracts to manage gas price volatility and basis swap contracts to reduce basis risk between HH prices and actual index prices at which the gas is sold.

Volumes per day associated with outstanding gas derivative contracts as of March 31, 2020 and the weighted average gas prices for those contracts are as follows: 

	2020						Year Ending December 31, 2021
	Second Quarter		Third Quarter		Fourth Quarter
Swap contracts:
Volume per day (MMBtu)	30,000		30,000		16,739		2,466
Price per MMBtu	$	2.41	$	2.41	$	2.43	$	2.46
Basis swap contracts:
Permian Basin index swap volume per day(MMBtu) (a)	30,000		30,000		16,739		2,466
Price differential ($/MMBtu)	$	(1.68)	$	(1.68)	$	(1.59)	$	(1.46)

______________________

(a)The referenced basis swap contracts fix the basis differentials between the index price at which the Company sells its Permian Basin gas and the NYMEX index prices used in swap contracts.

Contingent consideration. The Company's right to receive contingent consideration in conjunction with the South Texas Divestiture was determined to be a derivative financial instrument that is not designated as a hedging instrument. The contingent consideration of up to $450 million is based on oil and NGL prices during each of the five years from 2020 to 2024. See Note 3 and Note 4 for additional information.

Derivative accounting. The Company's derivatives are accounted for as non-hedge derivatives and therefore all changes in the fair values of its derivative contracts are recognized as gains or losses in the earnings of the periods in which they occur. The Company enters into commodity price derivatives under master netting arrangements, which, in an event of default, allows the Company to offset payables to and receivables from the defaulting counterparty.

Noncash gains and losses associated with the Company's commodity price derivatives and contingent consideration are separately presented in operating activities within the consolidated statements of cash flows.

Fair value. The fair value of derivative financial instruments not designated as hedging instruments is as follows:

As of March 31, 2020
Type	Consolidated Balance Sheet Location	Fair Value		Gross Amounts Offset in the Consolidated Balance Sheet		Net Fair Value Presented in the Consolidated Balance Sheet
		(in millions)
Assets:
Commodity price derivatives	Derivatives - current	$	386	$	—	$	386
Commodity price derivatives	Derivatives - noncurrent	$	43	$	—	$	43
Contingent consideration	Other assets - noncurrent	$	28	$	—	$	28
Liabilities:
Commodity price derivatives	Derivatives - current	$	3	$	—	$	3
Commodity price derivatives	Derivatives - noncurrent	$	3	$	—	$	3

As of December 31, 2019
Type	Consolidated Balance Sheet Location	Fair Value		Gross Amounts Offset in the Consolidated Balance Sheet		Net Fair Value Presented in the Consolidated Balance Sheet
		(in millions)
Assets:
Commodity price derivatives	Derivatives - current	$	32	$	—	$	32
Contingent consideration	Other assets - noncurrent	$	91	$	—	$	91
Liabilities:
Commodity price derivatives	Derivatives - current	$	12	$	—	$	12
Commodity price derivatives	Derivatives - noncurrent	$	8	$	—	$	8

Gains and losses on derivative contracts are as follows:

Derivatives Not Designated  as Hedging Instruments	Location of Gain (Loss) Recognized in Earnings on Derivatives	Three Months Ended March 31,
		2020		2019
		(in millions)
Commodity price derivatives	Derivative gain (loss), net	$	475	$	(13)
Contingent consideration	Interest and other income (loss), net	$	(63)	$	—
Interest rate derivatives	Derivative gain (loss), net	$	(22)	$	—

The Company uses credit and other financial criteria to evaluate the credit standing of, and to select, counterparties to its derivative instruments. Although the Company does not obtain collateral or otherwise secure the fair value of its derivative instruments, associated credit risk is mitigated by the Company's credit risk policies and procedures.

XML

Asset Retirement Obligations

3 Months Ended

Mar. 31, 2020

Asset Retirement Obligation [Abstract]

Asset Retirement Obligations

Asset Retirement Obligations

The changes in asset retirement obligations are as follows: 

	Three Months Ended March 31, 2020
	(in millions)
Beginning asset retirement obligations	$	191
New wells placed on production	1
Changes in estimates (a)	(5)
Liabilities settled	(16)
Accretion of discount	2
Ending asset retirement obligations	173
Less current portion of asset retirement obligations	(16)
Asset retirement obligations - noncurrent	$	157

______________________

(a)Changes in estimates are determined based on several factors, including abandonment cost estimates based on recent actual costs incurred to abandon wells, credit-adjusted risk-free discount rates, economic well life estimates and forecasted timing of abandoning wells.

XML

Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Cash flows from operating activities:
Net income	$ 289	$ 350
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion, depreciation and amortization	434	421
Impairment of inventory and other property and equipment	0	32
Exploration expenses, including dry holes	2	1
Deferred income taxes	76	103
Loss on disposition of assets, net	0	9
Accretion of discount on asset retirement obligations	2	3
Interest expense	5	1
Derivative related activity	(412)	17
Amortization of stock-based compensation	16	24
Investment in affiliate valuation adjustment	(145)	174
South Texas contingent consideration valuation adjustment	63	0
South Texas deficiency fee obligation	69	0
Other	31	62
Change in operating assets and liabilities:
Accounts receivable	479	(69)
Inventories	16	(36)
Other assets	21	(15)
Accounts payable	(284)	(74)
Interest payable	(35)	(29)
Other liabilities	(92)	(22)
Net cash provided by operating activities	825	604
Cash flows from investing activities:
Proceeds from disposition of assets, net of cash sold	1	6
Proceeds from investments	0	112
Additions to oil and gas properties	(639)	(741)
Additions to other assets and other property and equipment	(43)	(72)
Net cash used in investing activities	(681)	(695)
Cash flows from financing activities:
Borrowing under credit facility	800	0
Principal payments on long-term debt	(450)	0
Payments of other liabilities	(146)	(1)
Purchases of treasury stock	(122)	(222)
Dividends paid	(73)	0
Net cash provided by (used in) financing activities	9	(223)
Net increase (decrease) in cash, cash equivalents and restricted cash	153	(314)
Cash, cash equivalents and restricted cash, beginning of period	705	825
Cash, cash equivalents and restricted cash, end of period	$ 858	$ 511

XML

Other Expense (Tables)

3 Months Ended

Mar. 31, 2020

Other Income and Expenses [Abstract]

Schedule of components of other expense

The components of other expense are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
South Texas deficiency fee obligation (Note 4)	$	69	$	—
Termination and idle drilling and frac equipment charges (a)	8		4
Transportation commitment charges (b)	4		40
Legal and environmental charges	3		5
Restructuring charges (Note 3)	—		13
Asset impairment (Note 4)	—		28
Sand mine decommissioning-related charges (Note 3)	—		23
Vertical integration services (income) loss, net (c)	(4)		20
Other	5		14
	$	85	$	147

____________________

(a)Includes idle frac fleet fees, stacked drilling rig charges and drilling rig early termination charges.

(b)Primarily represents firm transportation payments on excess pipeline capacity commitments.

(c)For the three months ended March 31, 2019, amount includes $9 million of decommissioning operating expenses related to the Company's Brady sand mine and $15 million of carryover and winding down operating expenses related to the Company's sale of its pressure pumping services assets in December 2018. The components of the vertical integration services net margins are as follows:

	Three Months Ended March 31,
	2020		2019
	(in millions)
Gross revenues	$	11	$	35
Gross costs and expenses	$	7	$	55

XML

Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2020

Commitments and Contingencies Disclosure [Abstract]

Schedule of Schedule of Changes in Contract Obligations

The changes in contract obligations are as follows:

	Three Months Ended March 31, 2020
	(in millions)
Beginning contract obligations	$	468
Liabilities settled	(152)
Accretion of discount	3
Changes in estimate (a)	66
Ending contract obligations	$	385

______________________

(a)Represents changes in the Company's forecasted deficiency fee payments associated with the South Texas Divestiture and the difference between estimated and actual liabilities settled.

XML

Consolidated Balance Sheets (Parenthetical) - $ / shares	Mar. 31, 2020	Dec. 31, 2019
Statement of Financial Position [Abstract]
Common stock, par value (usd per share)	$ 0.01
Common stock, shares authorized	500,000,000
Common stock, shares issued	175,373,639	175,057,889
Treasury stock, shares	10,510,424	9,511,248

XML

Divestitures, Decommissioning and Restructuring Activities (Narrative) (Details) - USD ($) $ in Millions		1 Months Ended	3 Months Ended		42 Months Ended
	Jun. 30, 2019	May 31, 2019	Mar. 31, 2020	Mar. 31, 2019	Jul. 01, 2022	Jan. 01, 2021	Dec. 31, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash proceeds			$ 1	$ 6
Contingent consideration valuation adjustment (Note 4)			(63)	0
Contingent consideration			28				$ 91
South Texas deficiency fee obligation			69	0
Restricted cash			74				74
Accelerated depreciation			0	23
Significant Other Observable Inputs (Level 2)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contingent consideration			28				$ 91
South Texas Divestiture
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Deficiency fee liability		$ 348
South Texas Divestiture
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash proceeds		2
Cash proceeds, before normal closing adjustments		210
Receivable from buyer			70
Contingent consideration		136
Deficiency fee liability			(323)
South Texas Divestiture | Forecast
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Retained obligation percentage					100.00%
Escrow						$ 50
South Texas Divestiture | Maximum
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contingent consideration		450
Retained obligation percentage	100.00%
Deficiency fee liability			471
South Texas Divestiture | Maximum | Forecast
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Retained obligation percentage					100.00%
Buyer recovery percentage					18.00%
South Texas Divestiture | South Texas Divestiture
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Receivable from buyer		$ 72
Pressure pumping assets
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Accelerated depreciation				15
Impairment of inventory and other property and other equipment				15
Sand mine
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Accelerated depreciation			$ 23	9
Impairment of inventory and other property and other equipment				$ 13