20-F 1 v437523_20f.htm FORM 20-F

 

As filed with the Securities and Exchange Commission on April 28, 2016

 

 

 

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

 

 

 

FORM 20-F
ANNUAL REPORT PURSUANT TO
SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934

 

 

 

For the fiscal year ended December 31, 2015

Commission file number: 001-34175

ECOPETROL S.A.
(Exact name of Registrant as specified in its charter)

 

 

 

N/A
(Translation of Registrant’s name into English)

 

 

 

REPUBLIC OF COLOMBIA
(Jurisdiction of incorporation or organization)

 

 

 

Carrera 13 No. 36 – 24
BOGOTA – COLOMBIA
(Address of principal executive offices)
Tel. (571) 234 4000

 

 

 

Maria Catalina Escobar

Investor Relations Officer
investors@ecopetrol.com.co
Tel. (571) 234 5190
Carrera 13 N.36-24 Piso 7
Bogota, Colombia
(Name, Telephone, E-Mail and/or Facsimile number and Address of Company Contact Person)

 

Securities registered or to be registered pursuant to Section 12(b) of the Act.

 

 

 

Title of each class   Name of each exchange on which registered:
American Depository Shares (as evidenced by American Depository Receipts), each representing 20 common shares par value COP$609 per share   New York Stock Exchange
Ecopetrol common shares par value COP$609 per share   New York Stock Exchange (for listing purposes only)
7.625% Notes due 2019   New York Stock Exchange
4.250% Notes due 2018   New York Stock Exchange
5.875% Notes due 2023   New York Stock Exchange
4.125% Notes due 2025   New York Stock Exchange
7.375% Notes due 2043   New York Stock Exchange
5.875% Notes due 2045   New York Stock Exchange
5.375% Notes due 2026   New York Stock Exchange

 

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

 

Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act: None

 

Indicate the number of outstanding shares of each of the issuer’s classes of capital or common stock as of the close of the period covered by the annual report.

 

41,116,694,690 Ecopetrol common shares, par value COP$609 per share

 

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

 

x Yes ¨ No

 

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

 

¨ Yes x No

 

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

 

x Yes ¨ No

 

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

 

N/A

 

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

 

Large accelerated filer x Accelerated filer ¨ Non-accelerated filer ¨

 

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

 

¨ U.S. GAAP xInternational Financial Reporting Standards as issued by the International Accounting Standards Board ¨ Other

 

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

 

¨ Item 17 ¨ Item 18

 

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

 

¨ Yes x No

 

 

 

 

Annual Report on Form 20-F 2015

 

1. Introduction   1
               
  1.1 About This Report   1
         
  1.2 Forward-looking Statements   1
         
  1.3 Selected Financial and Operating Data   2
               
2. Strategy and Market Overview   4
               
  2.1 Our Corporate Strategy   6
               
3. Business Overview   8
               
  3.1 Our History   8
         
  3.2 Our Corporate Structure   9
         
  3.3 Our Business   10
         
  3.4 Exploration and Production   11
               
    3.4.1 Exploration Activities   11
               
      3.4.1.1 Exploration Activities in Colombia   11
               
      3.4.1.2 Exploration Activities Outside of Colombia   14
               
    3.4.2 Production Activities   15
               
      3.4.2.1 Production Activities in Colombia   16
               
        3.4.2.1.1. Ecopetrol S.A.’s Production Activities in Colombia   16
               
        3.4.2.1.2. Ecopetrol S.A.’s Affiliates and Subsidiaries’ Production Activities in Colombia   21
               
      3.4.2.2 Production Activities Outside Colombia   23
               
      3.4.2.3 Marketing of Crude Oil and Natural Gas   25
               
    3.4.3 Reserves   27
               
    3.4.4 Joint Venture and Other Contractual Arrangements   32
               
  3.5 Transportation and Logistics   35
               
    3.5.1 Open Access Business Model   35
               
      3.5.1.1 Transportation Activities   36
               
      3.5.1.2 Pipelines   39
               
      3.5.1.3 Export and Import Facilities   41
               
    3.5.2 Other Transportation Facilities   41
               
    3.5.3 Vice-Presidency of Transportation and Logistics   41

 

 ii 

 

 

    3.5.4 Marketing of Transportation Services   42
               
  3.6 Refining and Petrochemicals   42
               
    3.6.1 Refining   42
               
      3.6.1.1 Barrancabermeja Refinery   43
             
      3.6.1.2 Reficar   44
               
    3.6.2 Petrochemicals and Other Products   46
               
      3.6.2.1 Polipropileno del Caribe S.A.   46
             
      3.6.2.2 Biofuels   46
               
    3.6.3 Marketing and Supply of Refined Products   46
               
  3.7 Research and Development; Intellectual Property   47
         
  3.8 Applicable Laws and Regulations   48
               
    3.8.1 Principal Regulatory Bodies   48
           
    3.8.2 Regulation of Exploration and Production Activities   49
               
      3.8.2.1 Business Regulation   49
               
        3.8.2.1.1. Environmental Licensing and Prior Consultation   50
               
        3.8.2.1.2. Royalties   51
               
    3.8.3 Regulation of Transportation Activities   52
           
    3.8.4 Regulation of Refining and Petrochemical Activities   53
               
      3.8.4.1 Regulation of Liquefied Petroleum Gas (LPG) and Liquid Fuels   53
             
      3.8.4.2 Regulation Concerning Production and Prices   54
             
      3.8.4.3 Regulation of Biofuel and Related Activities   55
               
    3.8.5 Regulation of the Natural Gas Market   55
               
  3.9 Sustainability Initiatives   56
               
    3.9.1 HSE   56
               
      3.9.1.1 Ecopetrol S.A.   56
             
      3.9.1.2 Cenit   60
             
      3.9.1.3 Refinería de Cartagena   60
               
    3.9.2 Human rights   62
           
    3.9.3 Dow Jones Sustainability Index   63
           
    3.9.4 Environmental Sustainability   63

 

 iii 

 

 

      3.9.4.1 Environmental Practices   63
               
    3.9.5 Extractive Industries Transparency Initiative (EITI)   64
               
    3.9.6 Energy Projects   65
               
  3.10 Related Party Transactions   66
         
  3.11 Insurance   71
         
  3.12 Human Resources/Labor Relations   73
               
    3.12.1 Employees   73
               
    3.12.2 Collective Bargaining Arrangements   74
               
4. Financial Review   75
               
  4.1 Factors Affecting Our Operating Results   76
         
  4.2 Effect of Taxes, Exchange Rate Variation, Inflation and the Price of Oil on our Results   77
               
    4.2.1 Taxes   77
           
    4.2.2 Exchange Rate Variation   78
           
    4.2.3 Effects of Inflation   79
           
    4.2.4 Effects of the Price of Oil   79
               
  4.3 Accounting Policies   79
               
    4.3.1 Adoption of IFRS   79
               
  4.4 Critical Accounting Judgments and Estimates   80
               
  4.5 Operating Results   80
               
    4.5.1 Consolidated Results of Operations   80
               
      4.5.1.1 Total Revenues   81
             
      4.5.1.2 Cost of Sales   82
             
      4.5.1.3 Operating Expenses   83
             
      4.5.1.4 Finance Results, Net   83
             
      4.5.1.5 Income Tax   84
             
      4.5.1.6 Net Income (Loss) Attributable to Owners of Ecopetrol   84
             
      4.5.1.7 Segment Performance and Analysis   84
             
      4.5.1.8 Exploration and Production Segment Results   85
             
      4.5.1.9 Transportation and Logistics Segment Results   87
             
      4.5.1.10 Refining and Petrochemicals Segment Results   87

 

 iv 

 

 

  4.6 Liquidity and Capital Resources   88
               
    4.6.1 Review of Cash Flows   88
           
    4.6.2 Capital Expenditures   89
           
    4.6.3 Dividends   89
               
  4.7 Summary of Differences between Internal Reporting (Colombian IFRS and IFRS)   90
         
  4.8 Financial Indebtedness and Other Contractual Obligations   91
         
  4.9 Off Balance Sheet Arrangements   92
         
  4.10 Trend Analysis and Sensitivity Analysis   92
               
5. Risk Review   95
               
  5.1 Risk Factors   95
               
    5.1.1 Risks Related to Our Business   96
           
    5.1.2 Risks Related to Colombia’s Political and Regional Environment   105
           
    5.1.3 Legal and Regulatory Risks   109
           
    5.1.4 Risks Related to our ADSs   110
           
    5.1.5 Risks Related to State Ownership   113
               
  5.2 Risk Management   113
               
    5.2.1 Managing Risk through our Internal Control System   113
           
    5.2.2 Managing Information Security and Cybersecurity   114
           
    5.2.3 Managing Financial Risk   115
               
  5.3 Legal Proceedings and Related Matters   116
               
6. Shareholder Information   120
               
  6.1 2016 Shareholders’ General Assembly   120
         
  6.2 Dividend Policy   120
         
  6.3 Market and Market Prices   120
         
  6.4 Ecopetrol ADR Program Fees   123
         
  6.5 Taxation   124
               
    6.5.1 Colombian Tax Considerations   124
           
    6.5.2 U.S. Federal Income Tax Consequences   128
               
  6.6 Exchange Controls and Limitations   130
         
  6.7 Exchange Rates   132

 

 v 

 

 

  6.8 Major Shareholders   132
         
  6.9 Enforcement of Civil Liabilities   133
               
7. Corporate Governance   134
               
  7.1 Bylaws   134
         
  7.2 Code of Ethics   138
         
  7.3 Board of Directors   138
               
    7.3.1 Board Practices   140
           
    7.3.2 Board Committees   141
               
  7.4 Compliance with NYSE Listing Rules   142
         
  7.5 Management   144
         
  7.6 Compensation of Directors and Management   147
         
  7.7 Share Ownership of Directors and Executive Officers   147
         
  7.8 Controls and Procedures   147
               
8. Financial Statements   150
       
9. Signature Page   151
       
10. Exhibits   152
       
11. Cross-reference to Form 20-F   153

 

 vi 

 

 

1.Introduction

 

1.1About This Report

 

We file our Annual Report on Form 20-F and other information with the U.S. Securities and Exchange Commission.

 

We file reports, including annual reports on Form 20-F, and other information with the SEC pursuant to the rules and regulations of the SEC that apply to foreign private issuers. You may read and copy any materials filed with the SEC in the SEC’s public reference room at 100 F Street, NE, Washington, D.C. 20549. Please call the SEC at 1-800-SEC-0330 for further information on the operation of the public reference room. Any filings we make are also available to the public over the Internet at the SEC’s website at www.sec.gov and at our website at www.ecopetrol.com.co. (This URL is intended to be an inactive textual reference only. It is not intended to be an active hyperlink to our website. The information on our website, which might be accessible through a hyperlink resulting from this URL, is not and shall not be deemed to be incorporated into this annual report.)

 

Unless the context otherwise requires, the terms “Ecopetrol”, “we”, “us”, “our” or the “Company” are used in this annual report to refer to Ecopetrol S.A. and its subsidiaries on a consolidated basis.

 

References to the Nation in this annual report relate to the Republic of Colombia (“Colombia”), our controlling shareholder. References made to the Colombian government or the Government correspond to the executive branch including the President of Colombia, the ministries and other governmental agencies responsible for regulating our business.

 

1.2Forward-looking Statements

 

This annual report on Form 20-F contains forward-looking statements within the meaning of the safe harbor provisions of the U.S. Private Securities Litigation Reform Act of 1995. These statements are not based on historical facts and reflect our expectations for future events and results. Most facts are uncertain because of their nature. Words such as “anticipate”, “believe”, “could”, “estimate”, “expect”, “should”, “plan”, “potential”, “predicts”, “prognosticate”, “project”, “target”, “achieve” and “intend”, among other similar expressions, are understood as forward-looking statements. We have made forward-looking statements that address, among other things:

 

·our exploration and production activities, including drilling;

 

·import and export activities;

 

·our liquidity, cash flow, and sources of funding;

 

·our projected and targeted capital expenditures and other cost commitments and revenues; and

 

·dates by which certain areas will be developed or will come on-stream.

 

Our forward-looking statements are not guarantees of future performance and are subject to assumptions that may prove incorrect and to risks and uncertainties that are difficult to predict. Actual results could differ materially from those expressed or forecast in any forward-looking statements as a result of a variety of factors. These factors may include, but are not limited to, the following:

 

·general economic and business conditions, including crude oil and other commodity prices, refining margins and prevailing exchange rates;

 

·competition;

 

·our ability to obtain financing;

 

·our ability to find, acquire or gain access to additional reserves and our ability to develop existing reserves;

 

1

 

 

·uncertainties inherent in making estimates of our reserves;

 

·significant political, economic and social developments in Colombia and other countries where we do business;

 

·natural disasters, military operations, terrorist acts, wars or embargoes;

 

·regulatory developments, including regulations related to climate change;

 

·receipt of government approvals and licenses;

 

·technical difficulties; and

 

·other factors discussed in Section 5.1 of this document as “Risk Factors.”

 

All forward-looking statements attributed to us are qualified in their entirety by this cautionary statement. We undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information or for any other reason. Accordingly, readers should not place undue reliance on the forward-looking statements contained in this annual report.

 

1.3Selected Financial and Operating Data

 

The following table sets forth, for the periods and at the dates indicated, our selected historical financial and certain key operating data. The selected financial data has been derived from and should be read in conjunction with, and is qualified in its entirety by reference to, our consolidated audited financial statements, presented in Colombian Pesos.

 

Table 1 – Selected Operating Data

 

Operating Information  2015   2014   2013   2012   2011 
Oil and gas production (mboed)   760.7    755.4    788.2    754.0    724.1 
Proved oil and gas reserves (Mmboe)(1)   1,849    2,084    1,972    1,877    1,857 
Exploratory Wells(2)   5    28    22    23    39 
Refinery Through-put (bpd)(3)   234,861    240,484    283,362    296,340    305,631 
1P Reserves replacement ratio   6%   146%   139%   108%   164%

 

(1)For 2015 and 2014, proved reserves include natural gas royalties. Data for 2011 through 2013 excludes natural gas royalties. Data for all years excludes crude oil royalties.
(2)Gross exploratory wells.
(3)Refinery through-put includes Barrancabermeja, Reficar, Apiay and Orito. The Cartagena refinery was shutdown in March 2014 to complete an expansion program. The refinery has resumed operations and is expected to be up to full capability during the second half of 2016.

 

 2 

 

 

Financial Information

 

International Financial Reporting Standards (“IFRS”)

 

(Expressed in millions of Colombian Pesos, except for the net income per share and net operating income per share, which is expressed in Colombian Pesos)

 

Table 2 – Selected Financial Data

 

Financial Information  2015   2014 
Revenue   52,347,271    65,971,888 
Operating income   2,131,165    14,449,027 
Net (loss) income attributable to owners of the Company   (7,193,859)   5,046,517 
Net operating income per share   51.8    351.4 
Weighted average number of shares outstanding   41,116,694,690    41,116,698,456 
(Loss) earnings per share (basic and diluted)   (175.0)   122.7 
Total assets   123,588,190    110,923,851 
Total equity   43,100,963    48,534,228 
Subscribed and paid-in capital   25,040,068    10,279,175 
Number of common shares   41,116,694,690    41,116,698,456 
Dividends declared per share   -    133 
Total liabilities   80,487,227    62,389,623 

 

Our consolidated financial statements for the years ended December 31, 2014 and 2015 were prepared in accordance with IFRS as issued by IASB. References in this annual report to IFRS mean IFRS as issued by the IASB. Our date of transition to IFRS was January 1, 2014. These consolidated financial statements are our first financial statements prepared in accordance with IFRS.

 

Until December 31, 2014, we prepared our audited consolidated financial statements in accordance with Colombian Government Entity GAAP issued by the Contaduria General de la Nación with reconciliations to United States Generally Accepted Accounting Principles, or U.S. GAAP. As required by IFRS 1—First Time Adoption of International Financial Reporting Standards— our financial position and results of operations for the year ended December 31, 2014 have been restated in accordance with IFRS. Note 35 to our consolidated financial statements contains an analysis of the presentation and disclosure effects of adopting IFRS and the effects on equity and net income for the fiscal year ended December 31, 2014 as of January 1 and December 31, 2014. The selected financial information for 2014 included in this annual report differs from the information we previously published for 2014, because it is presented in accordance with IFRS for comparative purposes, as required by IFRS 1. Following our adoption of IFRS, we are no longer required to reconcile our financial statements to U.S. GAAP.

 

In addition, IFRS differs in certain significant respects from the current reporting standards as in effect in Colombia (“Colombian IFRS”) (which is the accounting standard we use for local reporting purposes). As a result, our financial information presented under IFRS is not directly comparable to any of our financial information presented under Colombian IFRS. For a description of the differences between Colombian IFRS and IFRS see section Financial ReviewSummary of Differences between Internal Reporting Policies and IFRS.

 

Our consolidated financial statements were consolidated line by line and all transactions and significant balances between affiliates have been eliminated. These financial statements include the financial results of all subsidiary companies controlled, directly or indirectly, by Ecopetrol S.A. See Exhibit 1 – Consolidated companies, associates and joint ventures, to our consolidated financial statements included in this annual report.

 

As indicated in paragraphs 9 and 18 of the International Accounting Standard 27 “Consolidated and Separated Financial Statements” we must present our financial information on a consolidated basis as if we were a single entity, combining the financial statements of Ecopetrol S.A. and its subsidiaries line by line, adding assets, liabilities, shareholder’s equity, revenues and expenses of similar nature, removing the reciprocal items among members of the Ecopetrol Group and recognizing non-controlling interest.  Beginning with this annual report, we will also be presenting our operating information on a consolidated basis.

 

The regulations of the SEC do not require foreign private issuers that prepare their financial statements on the basis of IFRS to reconcile such financial statements to U.S. GAAP. Accordingly, while we have in the past reconciled our consolidated financial statements prepared in accordance with Colombian Government Entity GAAP to U.S. GAAP, those reconciliations will no longer be presented in our filings with the SEC. We do continue to provide the disclosure required under the U.S. Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 932 “Extractive Activities—Oil and Gas” (which we refer to as ASC Topic 932), as this is required regardless of the basis of accounting on which we prepare our financial statements. Other than as required under ASC Topic 932, any references to accounting treatments under Colombian Government Entity GAAP or U.S. GAAP relate solely to the application of Colombian Government Entity GAAP or U.S. GAAP to our historical consolidated financial statements.

 

 3 

 

 

In this annual report, references to “US$” or “U.S. dollars” are to United States dollars and references to “COP$,” “Colombian Peso” or “Colombian Pesos” are to Colombian Pesos, the functional currency under which we prepare our financial statements. This annual report translates certain Colombian Peso amounts into U.S. dollars at specified rates solely for the convenience of the reader. Unless otherwise indicated, such Colombian Peso amounts have been translated at the rate of COP$2,743.39 per US$1.00, which corresponds to the Tasa Representativa Promedio del Mercado (TRM), or Average Representative Market Exchange Rate, for 2015. Such conversion should not be construed as a representation that the Colombian Peso amounts correspond to, or have been or could be converted into, U.S. dollars at that rate or any other rate. On April 22, 2016, the Representative Market Exchange Rate was COP$2,928.70 per US$1.00.

 

Certain figures shown in this annual report have been subject to rounding adjustments and, accordingly, certain totals may therefore not precisely equal the sum of the numbers presented. In this annual report a billion is equal to one with nine zeros.

 

2.Strategy and Market Overview

 

Since the second half of 2014, international crude oil benchmark prices have declined dramatically. From its peak in June 2014, the ICE Brent crude oil index monthly contract price fell by more than 65% by the end of 2015, directly impacting the revenue of oil producing companies. It is believed that the main reason behind the drop in prices is the imbalance between global supply and demand. According to estimates published by the Energy Information Administration (“EIA”), global oil demand increased 1.03 mboepd less than supply in 2015. Although non-OPEC supply grew 1.32 mboepd during 2015, it was at a slower pace as compared to 2014, primarily benefited from the United States, which increased 0.95 mboepd. Additionally, OPEC surprised the market by increasing its supply by 1.06 mboepd during 2015 and global demand grew 1.35 mboepd, mainly due to lower gasoline prices and higher economic growth in OECD countries, according to EIA.

 

Graph 1 – ICE BRENT$/BL Year 2015

(USD/BL)

 

 

 

 4 

 

 

Graph 2 – Annual Growth of Oil Demand and Supply Worldwide

(Mboepd)

 

 

 

Source: Energy Information Administration (EIA), “Short Term Energy Outlook” (January 12, 2016); PIRA Energy Group, “World Oil Market Forecast” (December 22, 2015).

 

These imbalances have caused a significant rise in global oil inventories during the past two years, with crude inventories from major OECD countries (US/EU/JP) rising by 117 million barrels during 2015. As of December 31, 2015, global inventories were an estimated 888 million barrels, according to PIRA Energy Group. Thus, overall business sentiment points to a sustained period of low crude oil prices i.e. in the range of US$30 per barrel – US$50 per barrel. The current environment will keep oil prices under pressure until supply is more balanced to demand and excess inventories of crude oil are consumed.

 

Although international oil prices and global demand and supply dynamics are significant factors affecting our business and financial condition, Colombia’s local economic factors have also influenced and could continue to influence our performance given that we conduct most of our business in Colombia.

 

The performance of Colombia’s gross domestic product (GDP) is one of the main drivers of fuel consumption in Colombia. According to the Ministry of Finance and Public Credit, in 2015, Colombia’s GDP grew by 3.1% in real terms, as compared to 4.6% GDP growth in 2014, driven mainly by the performance of the construction, retail, services and financial sectors. Despite the decrease in Colombia’s economic growth, local demand for liquid fuels (diesel, gasoline, jet fuel and LPG) increased by 8.3% mainly due to the increase in the number of vehicles in Colombia. The increase in the demand of liquid fuels also benefited from higher demand for gasoline and diesel following the closure of Colombia’s border with Venezuela, as customers in that area shifted their business to Ecopetrol; and higher consumption of thermal electricity during late 2015, due to warmer weather caused by the “El Niño” climate phenomenon, among other factors.

 

Recently, the Colombian government reduced its forecasted economic growth for 2016 from 3.5% to 3.2%, reflecting the impact of lower commodity prices, especially crude oil prices. The most important contributors to the expected economic output expansion in 2016 will be the construction sector (+3.8%) and the manufacturing sector (+7.5%), according to the Ministry of Finance and Public Credit. Growth in the manufacturing sector is expected to be influenced by the full operation of our subsidiary Refinería de Cartagena S.A. (“Reficar”) following the completion of its modernization project, expected to produce up to 10% of Colombia’s manufacturing output.

 

Despite these positive events, Colombia’s economy faces significant challenges as a result of the lower crude oil prices, given that the country is a net oil exporter, and the slow recovery of its main business and trading partners. These factors have resulted in an increase of the current account deficit in Colombia and have placed significant pressure on the exchange rate of the Colombian Peso against the U.S. dollar.

 

In September 2015, the Energy and Gas Regulatory Commission (“CREG”) for its acronym in Spanish issued the Resolution 213 that gave producers and clients the possibility to negotiate the index that would be used to update the prices of the existing natural gas contracts. 61% of Ecopetrol’s contracts defined the Consumer Price Index of Colombia as this index. The remaining 39% used a formula defined by CREG for those contracts in which producers and clients couldn’t reach an agreement. This formula defined by CREG includes one component related to variations of WTI (West Texas Intermediate) and another to the Producer Price Index of the United States.

 

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2.1Our Corporate Strategy

 

During the last decade Ecopetrol exhibited consistent growth that led it to consolidate its position as the largest corporation in Colombia and one of the 40 largest oil companies in the world (as reported in Energy Intelligence Top 100 2015). In May 2015 the board of directors of Ecopetrol (“Board of Directors”) approved the 2015 – 2020 strategy, based on sustainable value creation and a more efficient operation of Ecopetrol Group’s assets.

 

This strategy is aimed at fulfilling the expectations of Ecopetrol’s shareholders while at the same time enhancing Ecopetrol Group’s environmental and compliance frameworks.

 

The key guidelines for this strategy are the following:

 

1.Profitable Growth

 

üSeek successful exploration activity by restructuring Ecopetrol’s portfolio, achieving better geographic diversification and decreasing risk through, with focus on high value oil and gas plays.

 

üFocus production efforts on high priority mature fields and the development of projects to improve our recovery factor.

 

2.Operational and Financial Excellence

 

üImprove processes and innovate in order to operate more efficiently.

 

üPerform under specified financial discipline parameters, making sure that the Ecopetrol Group’s resources are invested in projects that generate value and sustainable growth.

 

üMaintain financial metrics within ranges that reflect long term sustainability, debt servicing and cash generation capacity.

 

3.Business Development

 

üTransform the organizational culture by creating a new collaborative environment and reinforcing human talent management.

 

üAchieve comprehensive and effective project management in terms of cost and schedules from the planning stage of a project through completion.

 

üDevelop a comprehensive environmental framework, to compliment the needs of our business and communities.

 

üEnforce a strong commitment to ethics and integrity across its business relations and its labor force.

 

To implement this strategy, during 2015 we designed and launched the 2015-2018 Transformation Program (the “Transformation Program”) comprised of eight key axes: efficiency, exploration, recovery factor, technology, projects, portfolio management, culture and leadership, and community relationships.

 

·With respect to efficiency, Ecopetrol expects to achieve cumulative structural savings through the implementation of best practices in processes and a focus on high-value activities.

 

·With respect to exploration, the Company started a plan to reinforce its technical capabilities in exploration and will launch a capacity-building technology program in order to create sustainable value.

 

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·With respect to the recovery factor, it has structured a comprehensive program for the improvement of the current oil recovery factor of 18%, which will maximize cash generation from current producing fields.

 

·With respect to technology, develop business technologies to compliment the Company’s strategy and to strengthen and streamline the Company’s information technology tools upon the capacities of Instituto Colombiano del Petroleo and the technical staff of the Company.

 

·With respect to project management, the Transformation Program includes a thorough review of the projects execution with the aim of optimizing capital allocation and ensuring that projects meet their budgets in terms of costs, time and profitability. Lessons learned from recent megaprojects undertaken (i.e. Reficar) will be imperative.

 

·With respect to portfolio management, the Company has a plan to generate cash by means of a dynamic portfolio rotation program to divest non-strategic assets and equity participations. For the period 2016 – 2017, we expect to raise funds between US$400 and US$900 million.

 

·With respect to culture and leadership, the Transformation Program includes actions intended to foster the corporate culture of Ecopetrol based on integrity, collaboration, creativity, care for life an operative and financial excellence; and enhance its human talent and leadership.

 

·With respect to community relationships, the Transformation Program includes the implementation of a new relationship model focused on the long-term sustainability of Ecopetrol’s operations by strengthening the ability of government entities and local organizations to foster greater prosperity in regions where Ecopetrol operates and to build safe and environmentally sustainable environments.

 

In 2015, the Transformation Program led to structural cost savings of approximately US$800 million vis-à-vis the original budget. The main areas where we saw cost savings were drilling and completion, crude dilution, transport, subsurface maintenance and fluid treatment, which represented 52% of savings, and supplies, services and technology, health, safety and environment (HSE) security and research and development, which represented 24% of savings. These savings reduced Ecopetrol’s costs of operations by 14% in 2015 as compared to 2014.

 

Consistent with this new corporate strategy in the long term, in December 2015, the Board of Directors approved a U.S.$4,800 million investment plan for the year 2016. However, the most recent review of oil price scenarios and the prioritization of the project’s portfolio in order to protect the cash flow and the financial health of the Company led to an adjustment of the capital expenditures for 2016, from U.S.$4,800 million to a range between U.S.$3,000 and U.S.$3,400 million. The plan aims at achieving an annual average production of around 715 thousand barrels of oil and gas equivalent per day in 2016 of which approximately 92% would be contributed by Ecopetrol S.A. and the remaining by its subsidiaries.

 

U.S.$2,156 million would be invested by Ecopetrol S.A. and U.S.$847 million by subsidiaries. 93% of the investment would be deployed in Colombia and the remaining 7% abroad. The highest percentage of resources will be allocated to exploration and production, followed by refining, mainly to the completion of the Cartagena refinery and the development of the transportation capacity. The detail of the investments approved per business segment of Ecopetrol S.A. and its subsidiary companies is as follows:

 

Table 3 – 2016 Investment Plan

 

Business Segment  (Millions of US$)   % Percentage
        
Exploration  $282    9.4%
Production   1,116    37.3%
Transportation and Logistics   433    14.4%
Refining, Petrochemicals, and Biofuels   1,135    37.8%
Others   34    1.1%
TOTAL  $3,000    100%

 

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3.Business Overview

 

3.1Our History

 

We were formed in 1951 by the Colombian government as Empresa Colombiana de Petróleos and began operating the crude oil fields at La Cira-Infantas, the oldest Colombian oil field whose production started in 1918, and the pipeline that connected that field with the Barrancabermeja Refinery and the port of Cartagena. In 1961, we assumed the direct operation of the Barrancabermeja Refinery and continued its transformation into an industrial complex. In 1974, we acquired the Cartagena Refinery, which had been in operation since 1957.

 

In 1970, we adopted our first bylaws that transformed us into a governmental industrial and commercial company administered by the Ministry of Mines and Energy. In 2003, we were transformed from an industrial and commercial company into a state-owned corporation, and renamed Ecopetrol S.A.

 

Pursuant to Decree Law 1760 of 2003, we were granted greater autonomy over our business decisions and we accelerated our exploration activities. In that year, the regulatory responsibilities formerly on Ecopetrol were allocated from then on blocks to private and public explorers and operators on a competitive basis. Since 2003, we have been evolving from a wholly state-owned entity to a mixed-economy company with private capital. This process has resulted in a substantial change in the legal framework to which we are subject and in the nature of our relationship with the Nation. We carried out our initial public offering in November 2007 when our common shares became listed on the Colombian Securities Exchange. Our American Depository Shares were listed on the New York Stock Exchange in 2008.

 

The following table sets forth a list of our material acquisitions since January 1, 2009 and the effective date as of which each acquisition has been reflected in our operating results.

 

Table 4 – Material Acquisitions since January 1, 2009

 

Company  Date  Participation
acquired in
transaction
   Sector 

Price (US$)(1)

Offshore International Group Inc.  February 2009   50%(2)  Exploration and Production  639 million
Oleoducto Central S.A. (Ocensa)  March 2009   24.7%(3)  Transportation  418 million
Hocol Petroleum Limited (Hocol)  March 2009   100%(4)  Exploration and Production  807 million
Refinería de Cartagena S.A. (Reficar)  May 2009   51%(5)  Refining  545 million
Equion Energía Limited (“Equion”)  January 2011   51%(6)  Exploration and Production  814 million

 

 

(1)Includes amounts of adjustment on transaction prices.
(2)U.S. parent of Savia Perú (formerly Petrotech Peruana S.A.).
(3)As a result of this transaction, our ownership of Oleoducto Central S.A. (“Ocensa”) increased to 60%.
(4)We acquired 100% of Maurel et Prom’s interest in Hocol Petroleum Limited, whose most important assets are Hocol S.A. and Homcol Cayman Inc. As a result of the acquisition, our ownership in Oleoducto de Colombia (“ODC”), increased from 43.85% to 65.57%.
(5)As a result of this transaction, we became the sole owner of Reficar.
(6)As a result of this acquisition, our ownership increased to 72.65% in Ocensa, 73.00% in ODC, and to 85.12% in Oleoducto del Alto Magdalena or OAM. We also obtained a 10.2% interest in Transgas de Occidente.

 

We are in the process of selling some of our non-core shareholdings:

 

·We currently own 3.03% of the total outstanding shares of Empresa de Energía de Bogotá. As approved by Decree 2305 of November 13, 2014, we are authorized to offer our remaining 3.03% of total outstanding shares of Empresa de Energía de Bogotá to the general public using the most appropriate mechanism for the volume and value of the remaining shares. The first stage of the divestment plan took place during the second quarter of 2015, in which we placed 352,872,414 shares at COP$1,740 per share.

 

·We currently own 1.23% of the total outstanding shares of Interconexión Eléctrica S.A. (“ISA”). As approved by Decree 1800 of September 9, 2015, we are authorized to offer our remaining 1.23% of the total outstanding shares to the general public using the most appropriate mechanism for the volume and value of the remaining shares. Pursuant thereto, during the second auction of the second stage of the divestment plan that took place on April 7, 2016, we placed 45,295,034 shares at COP$8,325 per share.

 

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·We currently own 100% of the total outstanding shares of Propilco. On January 27, 2016, the Board of Directors of Ecopetrol approved the commencement of a divestment plan to sell Ecopetrol’s shares in Propilco. As of the date of this annual report, the date of any potential transaction has not been established. We are in the process of obtaining administrative and governmental authorizations to divest our entire stake in Propilco, as prescribed by law. The next step in the process is to receive approval from the Council of Ministers of Colombia and the issuance of a Presidential Decree with the final approval to begin the divestiture process under Law 226 of 1995.

 

·We currently own 43.35% of the total outstanding shares of Inversiones de Gases de Colombia S.A. We are currently evaluating how to divest such equity stake. As of the date of this annual report, the timing for any divestment program has not been established.

 

3.2Our Corporate Structure

 

We operate in the following business segments: 1) Exploration and Production; 2) Transportation and Logistics; 3) Refining, Petrochemicals, and Biofuels.

 

Our subsidiaries Refinería de Cartagena (Reficar), Ecopetrol America Inc. and Ocensa are significant subsidiaries as such term is defined under SEC Regulation S-X.

 

We have a number of directly and indirectly held subsidiaries both in Colombia and abroad. Our subsidiaries are either directly owned by us or indirectly owned by us through one or more of our other subsidiaries. As of March 31, 2016, we have eight directly owned and 19 indirectly owned subsidiaries.

 

In January 2016, we organized a new wholly-owned subsidiary, Ecopetrol Costa Afuera Colombia S.A.S., which will be responsible for offshore exploration and production activities in Colombia. The new subsidiary seeks to develop offshore activities in Colombia, which the company currently carries out as operator and non-operator, and take advantage of the benefits of Decree 2682/14, pursuant to which the conditions and requirements are established for declaring the existence of Permanent Offshore Free Trade Zones.

 

The following table identifies our principal operating subsidiaries, their respective countries of incorporation, and our percentage ownership in each (both directly and indirectly through other subsidiaries), in each case as of March 31, 2016. See Exhibit 8.1 to this annual report for a complete list of our subsidiaries, their respective countries of incorporation, and our percentage of ownership in each.

 

Table 5 – Our Principal Operating Subsidiaries

 

COMPANY  COUNTRY OF
INCORPORATION
  OWNERSHIP % 
Exploration and Production        
Ecopetrol Óleo e Gás do Brasil Ltda.**  Brazil   100.00 
Ecopetrol del Perú S.A.**  Peru   100.00 
Ecopetrol Germany GmbH**  Germany   100.00 
Ecopetrol America Inc.**  United States   100.00 
Hocol S.A.**  Cayman Island   100.00 
Equion Energía Limited  United Kingdom   51.00 
Transportation        
Oleoducto de los Llanos Orientales S.A. (ODL)**  Panama   65.00 
Oleoducto de Colombia S.A.**  Colombia   73.00 
Oleoducto Central S.A.**  Colombia   72.65 
Oleoducto Bicentenario de Colombia S.A.S.**  Colombia   55.97 
Cenit Transporte y Logística de Hidrocarburos S.A.S.  Colombia   100.00 
Refining and Petrochemicals        
Refinería de Cartagena S.A.*  Colombia   100.00 
Polipropileno del Caribe S.A.*  Colombia   100.00 
Compounding and Masterbatching Industry Ltda.**  Colombia   100.00 
Biofuels        
Bioenergy S.A.**  Colombia   96.21 
Other        
Black Gold Re Ltd.  Bermuda   100.00 

 

 

*Direct and indirect participation.
**Solely indirect participation through other subsidiaries or affiliates.

 

 9 

 

 

The following organization chart illustrates the relationships between Ecopetrol S.A. and its direct and indirect subsidiaries as of March 31, 2016.

 

Graph 3 – Ecopetrol Corporate Structure

 

 

 

 

(a)Stock ownership of an Ecopetrol S.A.’s subordinate company.
(b)A foreing corporation with a foreing corporation branch in Columbia.
(c)As a result of the second auction on April 7, 2016, Ecopetrol S.A. sold 4.08% equity share in the company ISA. The final shareholding in ISA is 1.23%.

 

The stock ownership percentage listed refers to Ecopetrol S.A.’s direct and indirect participation. The data in this structure shows neither the whole ownership nor its decimal figures, so they will be used only for information purposes.

 

The so-called shareholding (Ecopetrol S.A.’s direct participation), affiliated, subsidiary companies are listed, as well as the stock interest of Ecopetrol S.A.’s subordinate companies.

 

3.3Our Business

 

We are a vertically integrated oil company with a presence primarily in Colombia, Peru, Brazil and the U.S. Gulf Coast. The Nation currently controls 88.49% of our voting capital stock. We are among the top 50 oil and gas companies in the world based on the (Petroleum Intelligence Weekly Top 50 Ranking) and in the top 5 in Latin America based on production volume. We are the largest corporation in Colombia as measured by revenues, EBITDA and shareholders’ equity, and we play a key role in the local hydrocarbon market.

 

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3.4Exploration and Production

 

Our exploration and production business segment includes exploration, development and production activities in Colombia and abroad. We began local exploration in 1955 and international exploration in 2006. We conduct exploration and production activities directly in Ecopetrol S.A., through some of our subsidiaries, and through joint ventures with third parties. As of December 31, 2015, we were the largest operator and the largest producer of crude oil and natural gas in Colombia, and we maintained the largest acreage under exploration in Colombia.

 

3.4.1Exploration Activities

 

Our exploration plan in Colombia is focused on: (i) exploration of sites in close proximity to existing producing areas, and (ii) currently producing basins and frontier areas, including off-shore areas primarily operated by our business partners, which we believe have the potential for large discoveries. We strive to balance these two focuses and develop the best mix of activities for our business. In addition, our exploration strategy for blocks, that are considered less attractive, is to look for business partners to share our interests or to sell our entire interest.

 

Our exploration strategy outside of Colombia is focused on locating prospects and establishing joint ventures with experienced operators. In order to implement this strategy, we have a Regional Studies team that manages our New Ventures and a Global Offshore team, which is responsible for ensuring the incorporation of contingent resources from the Caribbean Offshore in Colombia, the U.S. Gulf Coast and Brazil.

 

For purposes of this exploration section, “we” refers to Ecopetrol S.A., its subsidiaries and partnerships in which Ecopetrol has an interest. Unless otherwise stated, all figures are given before deductions for royalties.

 

3.4.1.1Exploration Activities in Colombia

 

Currently we have exploration activities in most of the sedimentary basins in Colombia, in which active oil and gas operations are found.

 

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The following map shows the basins where we are currently conducting exploration activities.

 

Graph 4 – Sedimentary Basins in Colombia

 

 

 

 12 

 

 

We conduct exploration activities in Colombia on our own and through joint ventures with regional and global oil and gas companies.

 

In 2015, Ecopetrol S.A. did not acquire any equivalent kilometers of seismic data either directly or through business partners.

 

Exploratory Wells

 

The following table sets forth, for the periods indicated, the number of gross and net productive and dry exploratory wells drilled by us and our joint venture partners and the exploratory wells drilled by third parties pursuant to sole risk contracts with us.

 

Table 6 – Ecopetrol S.A.’s Gross and Net Productive and Dry Exploratory Wells

 

   For the year ended December 31, 
   2015   2014   2013 
   (number of wells) 
COLOMBIA               
Ecopetrol S.A.               
Gross Exploratory Wells               
Owned and operated by Ecopetrol               
Productive(1)       3.0    4.0 
Dry(2)   1.0    9.0    2.0 
Total   1.0    12.0    6.0 
Operated by Partner in Joint Venture               
Productive   1.0    1.0    3.0 
Dry   1.0    2.0    2.0 
Total   2.0    3.0    5.0 
Operated by Ecopetrol in Joint Venture               
Productive       1.0     
Dry            
Total       1.0     
Net Exploratory Wells(3)               
Productive   0.5    4.1    5.5 
Dry   1.5    10.7    3.0 
Total   2.0    14.8    8.5 
Sole Risk               
Productive            
Dry            
Total            
Equion               
Gross Exploratory Wells               
Productive            
Dry            
Total            
Hocol               
Gross Exploratory Wells               
Productive   1.0        1.0 
Dry       4.0    6.0 
Total   1.0    4.0    7.0 
Net Exploratory Wells               
Productive   0.5        0.5 
Dry       3.0    5.0 
Total   0.5    3.0    5.5 

 

 

(1)A productive well is an exploratory well that has evidence of hydrocarbons.
(2)A dry well or hole is an exploratory well found to be incapable of producing either crude oil or natural gas in sufficient quantities to justify completion as a crude oil or natural gas well.
(3)Net exploratory wells are calculated according to our percentage of ownership in these wells.

 

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Ecopetrol S.A. drilled a total of three wildcat exploratory wells in 2015. There was evidence of hydrocarbons in one well: Kronos located in the Fuerte Sur Block in the Caribbean Offshore in Colombia, in which Ecopetrol holds a 50% working interest, in partnership with Anadarko (operator). Two wells were dry: Calasu and Muergana Sur.

 

In December 2014, Ecopetrol S.A. announced the discovery of hydrocarbons in the exploratory Orca-1 well (operated by Petrobras), in which Petrobras holds a 40% working interest, Ecopetrol holds a 30% working interest and Repsol holds a 30% working interest, and located 40 kilometers north of the Guajira province coast. It was the first discovery in deep water in the Caribbean Offshore in Colombia.

 

Our subsidiary Hocol drilled one successful exploratory well: Bullerengue-1 located in the SSJN-1 Block and operated by Hocol who holds a 50% working interest in partnership with Lewis Energy.

 

During 2015, bidding rounds were not launched by the National Hydrocarbons Agency to offer licenses for exploratory activities in Colombia.

 

3.4.1.2Exploration Activities Outside of Colombia

 

Our international exploration strategy is focused on participating in bidding rounds to secure blocks available for exploration and entering into joint ventures with international and regional oil companies. We believe exploring outside Colombia allows us to diversify our risks and improve the possibilities of increasing our crude oil and natural gas reserves.

 

With respect to our seismic data outside of Colombia, during 2015, our subsidiary Ecopetrol Brasil executed a seismic program on Ceará basin, CE-M-715 Block, having acquired 554.71 equivalent kilometers of seismic data, in which Ecopetrol Brasil holds a 50% working interest and Chevron (operator) holds the remaining 50%. Pursuant to their joint venture, Ecopetrol Brasil and Chevron will process the seismic data in 2016. In addition Ecopetrol Brasil established an alliance with the Japanese company JX Nippon Oil & Gas Exploration for exploration of the FZA-M-320 block, located in shallow waters off the Foz do Brasil basin, in the Equatorial rim of the Amazon. The joint venture agreement established that JX Nippon would join exploration in the area with a 30% stake.

 

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With respect to our exploratory drilling outside of Colombia, during 2015, in association with our business partners, we have undertaken deep water exploratory drilling in the U.S. Gulf Coast. The following table sets forth information on our exploratory drilling in the years 2015, 2014 and 2013.

 

Table 7 – Exploratory Drilling Outside of Colombia

 

   For the year ended December 31, 
   2015   2014   2013 
   (number of wells) 
INTERNATIONAL               
Ecopetrol America Inc.               
Gross Exploratory Wells               
Productive(1)       2.0     
Dry(2)   1.0    3.0    2.0 
Total   1.0    5.0    2.0 
Net Exploratory Wells(3)(4)               
Productive       0.7     
Dry   0.5    0.5    0.5 
Total   0.5    1.2    0.5 
Ecopetrol Óleo e Gás do Brasil Ltda.               
Gross Exploratory Wells               
Productive            
Dry           1.0 
Total           1.0 
Net Exploratory Wells               
Productive            
Dry           0.3 
Total           0.3 
Ecopetrol Germany               
Gross Exploratory Wells               
Productive            
Dry       2.0     
Total       2.0     
Net Exploratory Wells               
Productive            
Dry       0.2     
Total       0.2     
Savia Perú               
Gross Exploratory Wells               
Productive           1.0 
Dry            
Total           1.0 
Net Exploratory Wells               
Productive           0.5 
Dry            
Total           0.5 

 

 

(1)A productive well is an exploratory well that has evidence of hydrocarbons.
(2)A dry well or hole is an exploratory well found to be incapable of producing either crude oil or natural gas in sufficient quantities to justify completion as a crude oil or natural gas well.
(3)Net exploratory wells are calculated according to our percentage of ownership in these wells.
(4)None of our international wells were dug pursuant to a sole risk contract.

 

As set forth in the table above, in 2015, our subsidiary Ecopetrol America Inc. drilled the Sea Eagle exploratory well, in which the company has 50% working interest and our partner Murphy (operator) holds the remaining 50%. The well was declared a dry hole.

 

We also added 10 blocks to our exploration portfolio as a result of Ecopetrol America Inc.’s participation in partnership in the lease sale 235 and 246 which took place in June, September, October and November of the year 2015.

 

3.4.2Production Activities

 

Our consolidated average production was 760.7 thousand boepd in 2015, an increase of 5.3 thousand boepd as compared to 2014. This increase is mainly the result of an increase in production in the Castilla and Chichimene fields due to the entrance of new facilities and production wells, which contributed to higher average production in 2015.

 

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The following table summarizes the results of our oil and gas production activities for the periods indicated:

 

Table 8 – Ecopetrol Group’s Oil and Gas Production

 

   For the year ended December 31, 
   2015   2014   2013 
  

Oil(1)

   Gas   Total  

Oil(1)

   Gas   Total  

Oil(1)

   Gas   Total 
   (thousand boepd) 
Total production in Colombia(2)   619.2    130.4    749.6    610.9    133.3    744.2    643.9    136.6    780.5 
Total International production(3)   7.3    3.8    11.1    8.6    2.6    11.2    7.2    0.5    7.7 
Total production of Ecopetrol Group   626.5    134.2    760.7    619.5    135.9    755.4    651.1    137.1    788.2 

 

 

(1)Conversion between mcfpd and boepd is performed at 5,700 mcfpd to 1 boepd.
(2)Total production in Colombia corresponds to Ecopetrol S.A., Hocol and Equion.
(3)Total International production corresponds to Savia Perú and Ecopetrol America Inc.

 

3.4.2.1Production Activities in Colombia

 

3.4.2.1.1.Ecopetrol S.A.’s Production Activities in Colombia

 

For the year ended December 31, 2015, Ecopetrol S.A. was the largest participant in the Colombian hydrocarbons industry, accounting for approximately 58% of crude oil production (according to calculations made by Ecopetrol based on information from the National Hydrocarbons Agency) and approximately 60% of natural gas production (according to calculations made by Ecopetrol based on information from the National Hydrocarbons Agency).

 

In 2015, Ecopetrol S.A. carried out development drilling in all its producing regions in Colombia, drilling 539 development wells; 209 of those through direct operations and 330 through joint ventures. As part of an internal administrative restructuring process Ecopetrol S.A. reorganized the management of its production activities, which allowed it to improve its control on operations, while at the same time gave it a closer and more effective interaction with communities and partners. Beginning on July 1, 2014, Ecopetrol S.A.´s fully owned fields were divided into three main Vice-presidencies or administrative regions:

 

·Central Region: comprising 30 fields with active production in 2015 in the Middle Magdalena Valley and Catatumbo regions.

 

·Orinoquia Region: comprising 21 fields with active production in 2015 in the provinces of Meta, Casanare, Arauca y Vichada.

 

·Southern Region: comprising 35 fields with active production in 2015 in the provinces of Huila, Tolima, Putumayo, Nariño and Caquetá.

 

A fourth Vice-presidency, the Vice-presidency of Associated Assets, is responsible for all of the production activities in which a partner is involved, regardless of the location of such activities in Colombia. The Vice-Presidency of Associated Assets is comprised of 116 fields with active production in 2015.

 

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The map below indicates the locations of our operations in Colombia.

 

Graph 5 – Locations of our Production Operations in Colombia

 

 

 

Crude Oil Production

 

The average daily production of crude oil in Colombia by Ecopetrol S.A. (excluding its subsidiaries), was 586.2 mbod in 2015, 6.5 mbod higher than in 2014, which represents a year-to-year increase of 1%.

 

The following chart summarizes Ecopetrol S.A.’s average daily crude oil production in Colombia by Region Vice-Presidency, prior to deducting royalties, for the periods indicated.

 

Table 9 – Ecopetrol S.A.’s Average Daily Crude Oil Production in Colombia by Region Vice-Presidency

 

   For the year ended December 31, 
   2015   2014   2013 
   (thousand bpd) 
Central Region Vice-Presidency               
1) La Cira – Infantas   22.9    24.6    23.5 
2) Casabe   21.9    22.0    22.8 
3) Yarigui   17.8    16.7    14.9 
4) Other   23.7    21.0    20.3 
Total Central Region   86.3    84.3    81.4 
Orinoquía Region Vice-Presidency               
1) Castilla   122.5    104.4    112.9 
2) Chichimene   78.0    56.2    53.1 
3) Cupiagua   14.0    16.4    18.5 
4) Other   21.1    26.0    23.8 
Total Orinoquia Region   235.6    203.0    208.3 
Southern Region Vice-Presidency               
1) San Francisco   8.1    9.2    10.0 
2) Huila Area   7.8    8.2    7.9 
3) Tello   4.5    4.3    4.4 
4) Other   11.0    11.8    11.8 
Total Southern Region Vice-Presidency   31.4    33.6    34.2 
Associated Operations               
1) Rubiales   94.3    104.3    120.0 
2) Quifa   24.2    33.0    33.5 
3) Caño Limon   25.6    30.0    36.4 
4) Cusiana   5.2    7.0    8.8 
5) Other   83.6    84.6    90.0 
Total Associated Operations   232.9    258.9    288.7 
Total average daily crude oil production Ecopetrol S.A. (Colombia)   586.2    579.7    612.6 

 

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Table 10 – Ecopetrol S.A. Production per Type of Crude

 

  

2015

(mbod)

   Year-on-Year ∆
(%)
  

2014

(mbod)

   Year-on-Year ∆
(%)
  

2013

(mbod)

 
Light   44.6    0.2%   44.5    (9.4)%   49.1 
Medium   187.1    (5.8)%   198.6    (8.0)%   215.8 
Heavy   354.5    5.3%   336.6    (3.2)%   347.7 
Total   586,2    1.1%   579.7    (5.4)%   612.6 

 

Ecopetrol S.A.’s crude oil production during 2015 consisted of approximately 39% light and medium crudes and 61% heavy crudes. In 2014, approximately 42% of the crude oil production corresponded to light and medium crudes while the remaining 58% to heavy crudes. During 2013, production distribution was approximately 43% of light and medium crudes and 57% of heavy crudes.

 

Our most important heavy crude oil assets are:

 

·Cubarral Block. Located in the Orinoquia region and comprised of the Castilla and Chichimene fields. Together, these fields produced approximately 200 mbod in 2015.

 

·Rubiales - Quifa. The Rubiales and Quifa fields are part of our associated operations and are developed in joint venture with Metapetroleum. These fields produced 118 mbod in 2015. Both the Rubiales risk participation contract and the Piriri association contract expire on June 30, 2016 and Ecopetrol will take over full participation and the operation of the Rubiales field on July 1, 2016.

 

Natural Gas Production

 

In 2015, the average daily production of natural gas by Ecopetrol S.A. reached 121.2 mboed, including NGLs, a 3% reduction when compared with 2014 production.

 

We have three main natural gas production fields, Guajira, Cusiana and Cupiagua. The majority of our production of natural gas in Colombia is undertaken by joint ventures. In the Guajira field, we have partnered with Chevron. In the development of Cusiana field, our partners are Equion, Emerald Energy PLC and Santiago Oil Company. In contrast, Ecopetrol S.A. directly operates the Cupiagua field.

 

The Tauramena joint venture expires on July 3, 2016. The Tauramena block is part of the Cusiana unified exploitation plan wherein as a consequence of the termination of the Tauramena joint venture Ecopetrol’s participation will increase from 63.4% to 97.8%. Ecopetrol will assume the operation of the Cusiana unified exploitation plan as from the termination of the Tauramena joint venture.

 

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Of our total natural gas production as of December 31, 2015, approximately 35% was supplied from the Guajira field, approximately 22% from the Cusiana field, approximately 20% from the Cupiagua field and the remaining 23% from other fields.

 

The following table sets forth Ecopetrol S.A.’s average daily natural gas production in Colombia, including NGLs, prior to deducting royalties, for the years ended December 31, 2015, 2014, and 2013.

 

Table 11 – Ecopetrol S.A.’s Average Daily Natural Gas Production in Colombia

 

   For the year ended December 31, 
   2015   2014   2013 
   (thousand boepd) 
COLOMBIA               
Central Region               
1) La Cira – Infantas   0.12    0.16    0.14 
2) Casabe   0.00    0.00    0.04 
3) Yarigui   0.56    0.50    0.60 
4) Other   10.78    10.60    10.32 
Total Central Region   11.46    11.26    11.10 
Orinoquía Region               
1) Cupiagua   24.09    22.80    20.08 
2) Other   1.18    1.37    1.48 
Total Orinoquía Region   25.27    24.17    21.55 
Southern Region               
1) Huila Area   0.85    1.14    1.09 
2) Tello   0.35    0.26    0.20 
3) Other   0.03    0.04    0.02 
Total Southern Region   1.23    1.43    1.31 
Associated Operations               
1) Guajira   42.71    50.11    58.97 
2) Cusiana   27.03    26.53    23.93 
3) Other   13.47    11.87    12.04 
Total Associated Operations   83.21    88.52    94.94 
Total Natural Gas Production (Colombia)   121.17    125.38    128.90 

 

 

Note:Conversion between mcfpd and boepd is performed at 5,700 mcfpd to 1 boepd.

 

Projects to Increase the Recovery Factor:

 

During 2015, eight new pilot projects were initiated with the aim of increasing the recovery factor through water injection and chemical injection, meeting the goal of pilots that was originally set for the year. These pilots were developed in the fields, Provincia, Tisquirama, Llanito, Chichimente, Castilla, Suria and Caracara.

 

Among the key results for the year, the implementation of the water injection pilots into heavy crude fields of high importance for the company as Castilla and Chichimene is highlighted, which showed positive results in areas where the interventions took place, reporting an increase of around 1.8 mbod as of December 2015. This cumulative additional production currently represents an increase in the recovery factor of 1.2% in the area of contact of the Chichimene field pilot, and of 0.15% in the area of contact of the Castilla field pilot.

 

In addition, the air injection pilot project in Chichimene field reached 94% completion on construction of surface facilities, thereby completing most of the project’s main works. Connectivity tests were also concluded with positive results, demonstrating the continuity in the sands and the connection between the injection well and production wells. The start of air injection is planned for the fourth quarter of 2016.

 

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Including the pilot projects started in 2015, the Company currently has 29 recovery pilots underway, of which 22 have shown positive results in increasing pressure and 15 have shown an increase in crude production in the areas impacted.

 

Development Wells

 

The following table sets forth the number of gross and net development wells drilled exclusively by Ecopetrol S.A. and by its joint ventures in Colombia for the years ended December 31, 2015, 2014 and 2013.

 

Table 12 – Ecopetrol S.A.’s Gross and Net Development Wells in Colombia

 

   For the year ended December 31, 
   2015   2014   2013 
   (number of wells) 
COLOMBIA               
Central Region               
Gross wells owned and operated by Ecopetrol   79    104    67 
Orinoquía Region               
Gross wells owned and operated by Ecopetrol   109    65    77 
Southern Region               
Gross wells owned and operated by Ecopetrol   21    8    2 
Total gross wells owned and operated by Ecopetrol S.A. in Colombia   209    177    146 
Associated Operations               
Gross wells in joint ventures   330    584    628 
Net wells(1)   146    374    404 
Total gross wells in joint ventures Ecopetrol S.A. in Colombia   330    584    628 
Total net wells in joint ventures Ecopetrol S.A. in Colombia(1)   146    374    404 

 

 

(1)Net wells correspond to the ownership percentage of wells owned in joint ventures with our partners.

 

Production Acreage

 

The following table sets forth Ecopetrol S.A.’s developed and undeveloped gross and net acreage of crude oil and natural gas production in Colombia for the year ended December 31, 2015.

 

Table 13 – Ecopetrol S.A.’s Developed and Undeveloped Gross and Net Acreage of Crude Oil and Natural Gas Production in Colombia

 

   Production Acreage as of December 31, 2015
( acres)
 
   Developed   Undeveloped 
   Gross   Net   Gross   Net 
Ecopetrol S.A.   438,920    318,398    5,050,710    3,703,170 

 

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Gross and Net Productive Wells

 

The following table sets forth Ecopetrol S.A.’s total gross and net productive wells by region as of December 31, 2015.

 

Table 14 – Ecopetrol S.A.’s Gross and Net Productive Wells by Region

 

  

As of December 31, 2015

(number of wells)

 
  

Crude Oil(1)

  

Natural Gas(2)

 
   Gross   Net   Gross   Net 
COLOMBIA                    
Ecopetrol S.A.                    
Central region   2,264    1,824    10    10 
Orinoquía region   921    911    19    19 
Southern region   540    479    3    3 
Region of Associated Operations   3,202    1,558    24    9 
Total (Ecopetrol S.A.)   6,927    4,772    56    41 

 

 

Note:The above table reflects the productive wells that directly contribute to hydrocarbon production and therefore excludes wells used for injection, disposal, water abstraction, or other similar activities.

(1)We consider crude oil wells to be those in which the main operation is oil production, although many of these wells produce gas associated with oil production that, in some cases, have a commercial purpose.

(2)Natural gas wells are those in which operations are directed only toward the production of commercial gas.

 

3.4.2.1.2.Ecopetrol S.A.’s Affiliates and Subsidiaries’ Production Activities in Colombia

 

Crude Oil Production

 

The following table sets forth our average daily crude oil production from Hocol and Equion, prior to deducting royalties, for the periods indicated.

 

Table 15 – Ecopetrol S.A.’s Subsidiaries in Colombia Average Daily Crude Oil Production

 

   For the year ended December 31, 
   2015   2014   2013 
   (thousand bpd) 
COLOMBIA               
Hocol               
Joint venture operation   2.1    2.5    2.6 
Direct operation   19.3    18.8    18.6 
Total Hocol   21.4    21.3    21.2 
Equion               
Joint venture operation            
Direct operation   11.6    10.0    10.1 
Total Equion   11.6    10.0    10.1 
Production tests            
Total average daily crude oil production (Subsidiaries in Colombia)   33    31.3    31.3 

 

Hocol’s 0.5% production increase in 2015 as compared to 2014 was mainly due to: (1) an increase in production from the Pintado Norte 1, Guarrojo 8, La Cañada 19 and La Cañada 20 wells which were drilled in December 2014 and (2) the transfer of Ecopetrol’s ownership in Toldado, Quimbaya, Toy, Toqui-Toqui, Totare, Rio Saldaña Puli and Chenche fields to Hocol.

 

Equion’s 16% production increase in 2015 as compared to 2014 was mainly due to higher base production in the Piedemonte fields.

 

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Natural Gas Production

 

The following table sets forth our subsidiaries’ average daily natural gas production, prior to deducting royalties, for the periods indicated.

 

Table 16 – Ecopetrol S.A.’s Subsidiaries in Colombia Average Daily Natural Gas Production

 

   For the year ended December 31, 
   2015   2014   2013 
   (thousand boepd)(1) 
Hocol               
Joint venture operation   0.0         
Direct operation   0.2    0.1    0.2 
Total Hocol   0.2    0.1    0.2 
Equion               
Joint venture operation            
Direct operation   9    7.8    7.5 
Total Equion   9    7.8    7.5 
Production Tests            
Total Natural Gas Production (Subsidiaries in Colombia)   9.2    7.9    7.7 

 

 

Note:  Conversion between mcfpd and boepd is performed at 5,700 mcfpd to 1 boepd.

 

Development Wells

 

The following table sets forth the number of gross and net development wells drilled exclusively by our subsidiaries and in their joint ventures in Colombia for the periods indicated.

 

Table 17 – Ecopetrol S.A.’s Subsidiaries in Colombia Gross and Net Productive Wells

 

   For the year ended December 31, 
   2015   2014   2013 
   (number of wells) 
Hocol               
Gross wells owned and operated by Hocol   13    16    18 
Gross wells in joint ventures   1    6    4 
Net wells(1)   13    17    18 
Equion               
Gross wells owned and operated by Equion   5    2    6 
Gross wells in joint ventures            
Net wells(1)   1    1    2 
Total gross wells owned and operated in Colombia   18    18    24 
Total gross wells in joint ventures in Colombia   1    6    4 
Total net wells (Subsidiaries in Colombia)   14    18    20 

 

 

(1)Net wells correspond to the sum of wells owned and operated by our subsidiaries and their ownership percentage of wells owned in joint ventures with their partners.

 

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The following table sets forth our subsidiaries’ developed and undeveloped gross and net acreage of crude oil and natural gas production in Colombia for the year ended December 31, 2015.

 

Table 18 – Ecopetrol S.A.’s Subsidiaries in Colombia Developed and Undeveloped Gross and Net Acreage of Crude Oil Production

 

   Production acreage as of December 31, 2015 
   Developed   Undeveloped 
   Gross   Net   Gross   Net 
   (in acres) 
Hocol   4,752    4,424    702    678 
Equion   30,113    6,512    109,437    22,557 
Total (Subsidiaries in Colombia)   34,865    10,946    110,139    23,235 

 

The following table sets forth our subsidiaries’ total gross and net productive wells in Colombia for the year ended December 31, 2015. We consider crude oil wells to be those in which the main operation is oil production, although many of these wells produce gas associated with oil production that, in some cases, have a commercial purpose. Natural gas wells are those in which operations are directed only towards production of commercial gas. Information in the table below reflects productive wells that directly contribute to hydrocarbons production and therefore excludes wells used for injection, disposal, water abstraction, or other similar activities.

 

Table 19 – Ecopetrol S.A.’s Subsidiaries in Colombia Developed and Undeveloped Gross and Net Acreage of Natural Gas Production

 

   As of December 31, 2015 
   Crude Oil   Natural Gas 
   (number of wells) 
   Gross   Net   Gross   Net 
Hocol   269    197    3    2 
Equion   41    17    41    17 
Total Subsidiaries in Colombia   310    214    44    19 

 

3.4.2.2Production Activities Outside Colombia

 

Crude Oil Production

 

The following table sets forth our average daily crude oil production outside Colombia, prior to deducting royalties, for the periods indicated.

 

Table 20 – Ecopetrol S.A.’s Subsidiaries Outside Colombia Average Daily Crude Oil Production

 

   For the year ended December 31, 
   2015   2014   2013 
   (thousand bpd) 
Savia Perú   4.8    5.9    5.0 
Ecopetrol America Inc.   2.5    2.6    1.4 
Total average daily crude oil production (International)   7.3    8.5    6.4 

 

Natural Gas Production

 

The following table sets forth our average daily natural gas production outside Colombia, prior to deducting royalties, for the periods indicated.

 

Table 21 – Ecopetrol S.A.’s Subsidiaries Outside Colombia Average Daily Natural Gas Production

 

   For the year ended December 31, 
   2015   2014   2013 
   (thousand boepd) 
Savia Perú   1.2    0.5    0.3 
Ecopetrol America Inc.   2.6    2.1    0.2 
Total average daily natural gas production (International)   3.8    2.6    0.5 

 

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The following table sets forth the number of gross and net development wells outside Colombia, drilled exclusively by us and in joint ventures for the periods indicated. Information in the table below reflects productive wells that directly contribute to hydrocarbons production and therefore excludes wells used for injection, disposal, water abstraction, or other similar activities.

 

Table 22 – Ecopetrol S.A.’s Subsidiaries Outside Colombia Gross and Net Productive Wells

 

   For the year ended December 31, 
   2015   2014   2013 
   (number of wells) 
Savia Perú               
Gross wells   0    13    20 
Net wells(1)   0    6.5    10 
Ecopetrol America Inc.               
Gross wells   2    -    - 
Net wells(1)   0.4    -    - 
Total gross wells (International)   2    13    20 
Total net wells (International)   0.4    6.5    10 

 

 

(1)Net wells correspond to the sum of wells entirely owned by us or our subsidiaries and our ownership percentage of wells owned in joint ventures with our partners.

 

The following table sets forth our developed and undeveloped gross and net acreage of crude oil and natural gas production outside Colombia for the year ended December 31, 2015.

 

Table 23 – Ecopetrol S.A.’s Subsidiaries Outside Colombia Developed and Undeveloped Gross and Net Acreage of Crude Oil and Natural Gas Production

 

   Production acreage as of December 31, 2015 
   Developed   Undeveloped 
   Gross   Net   Gross   Net 
   (in acres) 
Savia Perú   137,246    79,575    57,671    1,095 
Ecopetrol America Inc.(1)   49,680    10,645    18,261    1,095 
Total (International)   186,926    90,220    75,932    2,190 

 

 

(1)Production and acreage from Ecopetrol America Inc. is related to the K2, Dalmatian and Gunflint field blocks in the Gulf of Mexico. For K2, there are four blocks in the production stage. For Dalmatian, there are six blocks, five of which are held by production. For Gunflint, there are four blocks held by suspension of production until the production starts.

 

The following table sets forth our total gross and net productive wells outside Colombia for the year ended December 31, 2015.

 

Table 24 – Ecopetrol S.A.’s Subsidiaries Outside Colombia Gross and Net Productive Wells

 

   As of December 31, 2015 
   Crude Oil 
   Gross   Net 
   (number of wells) 
INTERNATIONAL          
Savia Perú   650    325 
Ecopetrol America Inc.   11    1.64 
Total (International)   661    326.64 

 

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3.4.2.3Marketing of Crude Oil and Natural Gas

 

In 2015, Ecopetrol sold 1,005.9 mboepd, out of which 550.7 mboepd represented sales of crude oil (54.7%), 92.5 mboepd natural gas (9.2%) and 362.7 mboepd of fuels and petrochemicals (36.1%).

 

Export sales of crude oil increased by 5.2 mbopd as compared to 2014 primarily due to the growth in Ecopetrol’s crude oil production and higher volumes being moved through our transportation systems, mainly Caño Limón – Coveñas pipeline due to a decline in the number of attacks against our infrastructure. Domestic sales of crude oil fell 40.4% (9.1 mbopd) because customers that produce IFOS (Intermediate Fuel Oil) for the bunkers industry in Colombia switched to buying fuel oil from the Barrancabermeja Refinery, thereby reducing our crude oil sales.

 

Despite higher demand by thermal power plants due to “El Niño” climate phenomenon, Ecopetrol’s natural gas sales fell 8.6% (8.7 mboepd) as compared to 2014 due to the expiration of the contract for gas exports to Venezuela in June 2015 and the decline of Guajira field.

 

Crude Oil Export Sales

 

Our crude oil export sales are made both in the spot market and through term contracts, primarily to refiners in Asia, the U.S. Gulf Coast, U.S. Atlantic Coast, Europe, Central America and the Caribbean.

 

The Castilla blend is the principal type of crude oil for foreign sales, with 348 mbopd sold during 2015 (a 73.5% share of our crude oil basket) representing an 11.1 mbopd increase as compared to 2014, followed by the Vasconia Norte blend with 67.4 mbopd (a 14.2% share in our crude oil basket) representing a 2.4 mbopd decrease as compared to 2014. While South Blend sales decreased approximately 7.7 mbopd, mainly due to lower availability of the Oleoducto Trasandino in comparison to 2014, this decrease was partially offset by an increase in Magdalena Blend sales of approximately 4.2 mbopd.

 

In 2015, the price of our crude basket decreased by US$43.4 per barrel, as compared to 2014, due primarily to a general decline in international prices as the decline in the price of the ICE Brent was close to US$45.85 per barrel (according to Bloomberg).

 

A market diversification strategy has allowed Ecopetrol to improve its presence in markets other than the U.S. Gulf Coast, a destination that experienced a decrease in our crude oil exports, in terms of volume, from 28.6% of total export sales in 2014 to 23.7% in 2015. In contrast, other destinations, such as the U.S. Atlantic Coast and the U.S. West Coast, experienced an increase in crude oil exports, in terms of volume, from 6.9% of total export sales in 2014 to 12.6% in 2015. In particular, exports to the U.S. West Coast enabled Ecopetrol to capture a higher value for its crude oil from some of the most profitable refining hubs in the world.

 

Ecopetrol’s crude oil sales volume to the Asian market decreased from 37.2% in 2014 to 31.6% in 2015 mainly due to: (i) the increased supply coming into this market from the Middle East and (ii) the increase in opportunities for Ecopetrol S.A. to sell in the Caribbean and Central America spot market, where some clients temporarily stored crude oil. The Central America and Caribbean market represented 17.4% of our total crude oil exports in 2015, followed by the European market, which represented 12.9% of our total crude oil exports.

 

Crude Oil Purchase Contracts

 

Ecopetrol has signed a number of crude oil purchase contracts with third parties. We also purchase crude oil received by the ANH as royalties from us and other producers in Colombia. Crude oil purchased from the ANH and our business partners is either processed in our refineries or exported. The purchase price is negotiated as an export parity, which discounts logistic costs and quality adjustments, based on international market prices, plus a commercial fee.

 

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The term of some of our purchase contracts is linked to the term of the exploration and production contracts signed with our business partners. Other clauses of the contracts such as price and place of delivery may be subject to renegotiation during the term of the contract. Certain purchase contracts not linked to joint venture agreements may be extended and renegotiated by the parties.

 

The table below sets forth the volumes of crude oil purchased from our business partners and third parties and volumes of crude oil purchased from the ANH corresponding to royalties for the years ended December 31, 2015 and 2014.

 

Table 25 – Ecopetrol Consolidated Crude Oil Purchases

 

   For the year ended December 31, 
   2015   2014 
   (million barrels) 
Ecopetrol Corporate Group          
Crude oil purchased from the ANH   45.6    45.4 
Crude oil purchased from third parties   15.6    20.9 

 

Import of Diluents

 

In 2015 we increased by 10.8% (6.3 mboepd) the imports of diluents (principally naphtha) used to allow our heavy crudes to be pumped through pipelines, as compared to 2014, due to an increase in production of heavy crude oil and a change in the quality specifications of our diluents.

 

Natural Gas Sales

 

In 2015, we supplied 656.4 gbtud of the total natural gas demand in Colombia, representing a market share of 63.5% (according to calculations made by Ecopetrol S.A. and Hocol based on internal information and data from Concentra – Inteligencia SAS) which is stable as compared to 2014, with production used for our own consumption at refineries and for sale to natural gas distributors. Our market share in 2015, including foreign sales, was 63.0% and 63.4% in 2014.

 

Despite the increase in local demand from power plants to 143.7 gbtud in 2015 from 131.1 gbtug in 2014, total demand for natural gas in 2015 decreased 7.3% compared to the previous year. Demand in 2015 was 1,071 gbtud, mainly as a result of the completion of our export contract with Venezuela in 2015. For 2014 demand for natural gas was 1,155 gbtud.

 

Ecopetrol sells natural gas to distribution companies through firm, interruptible and conditional contracts. These distributors supply natural gas to the residential market, for compressed natural gas for vehicles and to industries in Colombia. We also market and sell natural gas to the industrial sector and to gas-fired and combined cycle power plants.

 

Ecopetrol S.A. also exports natural gas. In 2007, we and our partner Chevron entered into a long-term natural gas supply contract with PDVSA. This contract was amended in June 2014, and expired on June 30, 2015. In the first half of 2015, Chevron and Ecopetrol sold 38 gbtud to PDVSA, from which 19 gbtud was exported by us and the remaining 19 gbtud were exported by Chevron. In 2014, Chevron and Ecopetrol delivered 98 gbtud to PDVSA, exceeding the quantity of natural gas we agreed to supply in our gas export contract. Of the total volume of gas delivered in 2014 to PDVSA, 66% came from us and 34% came from Chevron. In 2013 and 2012, Chevron and Ecopetrol delivered 204 gbtud and 186 gbtud respectively. Pursuant to the terms of the agreement, Chevron assumed 43%, and Ecopetrol 57%, of the responsibility to deliver natural gas to PDVSA.

 

Natural Gas Delivery Commitments

 

In August 2013, the CREG issued natural gas sale guidelines through Resolution 089 of 2013. Ecopetrol S.A., in accordance with those guidelines, initiated a marketing process for natural gas during 2015, in which nine contracts were signed with seven different companies, which contract commitments are mandatory for the buyers. Through that process, Ecopetrol S.A. sold 100% of Ecopetrol’s Guajira gas (5.47 gbtud available for commitments of one year) and 98% of the Ecopetrol’s available gas from the Cusiana and Cupiagua fields for five years (56.55 gbtud). Those commitments are in addition to the existing agreements (approximately 24.1 gbtud from Guajira and approximately 233.8 gbtud from the Cusiana and Cupiagua fields) due to expire in 2018.

 

 26 

 

 

The table below sets forth the commitments we have in Colombia under firm contracts with local natural gas distribution companies, local industries, gas fired power generators, and internal agreements with our refineries and fields.

 

Table 26 – Ecopetrol Consolidated Third Parties and Self-consumption Volumes

 

   For the year ended December 31, 
   2016   2017   2018   2019 
   (gbtud) 
Volume for sales third parties   501.7    501.1    479.8    261.1 
Volume for self-consumption   211.3    225.2    231.1    269.1 
Total Commitments   713.0    726.3    710.9    530.2 

 

Ecopetrol America Inc. is not included in the table above. In respect of Ecopetrol America Inc., it does not have any natural gas delivery or supply commitments. The natural gas produced at Ecopetrol America Inc.’s K2 field is purchased by CIMA Energy Ltd. at the Neptune Gas Plant in Louisiana and the natural gas produced at Ecopetrol America Inc.’s Dalmatian field is purchased by Murphy E & P at the Petronious Platform. Neither of these arrangements has minimum or maximum quotas.

 

3.4.3Reserves

 

The reserves audit process was conducted in accordance with SEC definitions and rules set forth in Rule 4-10(a) of Regulation S-X and the disclosure guidelines contained in the SEC’s Modernization of Oil and Gas Reporting final rule dated December 31, 2008 and effective as of January 1, 2010.

 

The estimated reserve amounts presented in this report, as of December 31, 2015, are based on the average prices during the 12-month period prior to the ending date of the period covered in this report, determined as the unweighted arithmetic averages of the prices in effect on the first day of the month for each month within such period, unless prices were defined by contractual arrangements, as required by the SEC regulations.

 

Our crude oil and natural gas net proved reserves include reserves from our subsidiaries located in the United States (Gulf of Mexico) and Peru, and Equion and Hocol’s assets in Colombia.

  

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Estimated Net Proved Reserves

 

The following table sets forth our estimated net proved developed reserves of crude oil and gas by region for the years ended December 31, 2015, 2014 and 2013.

 

Table 27 – Net Proved Developed Reserves

 

Net Proved Developed Reserves  Colombia   North
America
   South
America
excluding
Colombia
   Total 
Net Proved Developed oil reserves in million barrels oil equivalent                    
At December 31, 2013   870    1    9    880 
At December 31, 2014   967    2    10    979 
At December 31, 2015   849    3    6    858 
Net Proved Developed NGL reserves in million barrels oil equivalent                    
At December 31, 2013   52    0    1    53 
At December 31, 2014   62    0    1    63 
At December 31, 2015   54    0    1    55 
Net Proved Developed gas reserves in billion standard cubic feet                    
At December 31, 2013   2,654    2    7    2,663 
At December 31, 2014   3,260    14    9    3,284 
At December 31, 2015   3,156    16    5    3,176 
Net Proved Developed oil, NGL and gas reserves in million barrels oil equivalent                    
At December 31, 2013   1,387    2    11    1,400 
At December 31, 2014   1,602    5    12    1,618 
At December 31, 2015   1,457    5    7    1,470 

 

 

The conversion rate used is 5,700 standard cubic feet = 1 barrel of oil equivalent.

 

We are required, as are all oil companies undertaking exploratory and production activities in Colombia, to pay a percentage of our production to the Government as royalties. However, the ANH’s Resolution 877 of 2013, Resolution 351 of 2014 and Resolution 640 of 2014 require natural gas royalties to be paid in cash, which means that the determination of the property rights to the quantities of natural gas we produce is based on the total volume produced without deductions on account of royalties. The main producing gas fields are Cusiana, Cupiagua, Pauto, Chuchupa, Gibraltar, and Ballena which represent 93% of our gas reserves due to the change in the form of royalty payments.

 

The following table summarizes our proved oil, NGL and natural gas reserves, which includes 237.8 billion standard cubic feet of fuel gas within our natural gas results and 744.6 billion cubic feet of royalties, as of December 31, 2015.

 

Table 28 – Proved Oil, NGL and Natural Gas Reserves

 

Reserves Category  Oil (million
barrels)
   NGL (million
barrels)
   Natural Gas
(bcf)
   Total Oil and
Gas (Mmboe)
 
PROVED DEVELOPED RESERVES                    
Total (Colombia)   849    54    3,156    1,457 
International                    
North America   3    0    16    5 
South America   6    1    5    7 
TOTAL PROVED DEVELOPED RESERVES   858    55    3,176    1,470 
PROVED UNDEVELOPED RESERVES                    
Total (Colombia)   295    17    291    364 
International                    
North America   7    0    9    9 
South America   6    0    3    7 
TOTAL PROVED UNDEVELOPED RESERVES   308    18    303    379 
TOTAL PROVED RESERVES   1,166    73    3,479    1,849 

 

 

The conversion rate used is 5,700 standard cubic feet = 1 barrel of oil equivalent.

 

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Reserves Replacement

 

The reserves replacement ratio is defined as the sum of additions and revisions of proved reserves divided by produced volumes in any given period. The following table presents the changes in reserves in each category relating to the reserve replacement ratio for the years 2015, 2014 and 2013.

 

Changes in Proved Reserves

 

Table 29 – Changes in Proved Reserves

 

   As of December 31 
  2015   2014   2013 
Consolidated Company (million barrels oil equivalent) (1)            
Revisions of previous estimates   (25)   270    232 
Purchase of Minerals   0    0    9 
Improved Recovery   16    34    27 
Extensions and discoveries   24    51    75 
Sales   0    0    (3)
Total reserves additions   16    355    340 
Production   (251)   (243)   (245)
Net change in proved reserves   (235)   112    95 

 

 

(1)Includes Fuel gas and royalties (28 billion standard cubic feet).

 

The reserves replacement ratio for 2015 was 0.06 compared to 1.46 in 2014. The average replacement ratio for the last three years was 0.97.

 

Table 30 – Reserves Replacement Ratio

 

   As of December 31 
   2015   2014   2013 
Reserves replacement ratio (including purchase and sales)               
Annual   0.06    1.46    1.39 
Three year average   0.97    1.31    1.37 

 

Revisions of Previous Estimates

 

In 2015, revisions reduced reserves by 25 million boe due to economic factors and reevaluated projects, together resulting in a decrease of 199 million boe, as follows: (i) economic factors, primarily the substantial decrease in oil prices, led to a 141 million boe decrease in reserves (the ICE Brent crude price was 45% lower in 2015 as compared to 2014, which resulted in the lowering of economic limits in some of our fields) and (ii) our portfolio of projects decreased by 58 million boe.

 

This decrease was partially offset by:

 

(i)Better production in our existing fields, as a result of new drilling operations mainly in the Castilla and Rubiales fields and positive revisions of some fields (+122 million boe) due to better than expected production performance, such as in the Chichimene field amongst other fields (+6 million boe). In addition, positive revisions were primarily driven by the Company’s Transformation Program that led to a better cash flow due to higher operational efficiency.

 

(ii)Development projects in the Cajua, Castilla, Chichimene, Pauto, Quifa, Rubiales, and Yarigui – Cantagallo fields, which resulted in a 97.2 million boe increase in reserves.

 

(iii)A 47 million boe increase in fuel gas reserves, which represented 2.5% of total reserves and are composed of 13 producer’s fields: Ballena, Chuchupa, Cupiagua, Cusiana, Floreña, Gibraltar, Infantas, La Cira, Pauto, Provincia, Recetor, and Yarigui.

 

Improved Recovery

 

In 2015, improved recovery increased reserves by 15.8 million boe. The additions were associated with the continued development of waterflood projects through existing wells, although additional drilling may be required to fully optimize the development configuration. The main additions were in Dina Cretaceo, La Cira, Tibú, Palogrande, and Casabe fields, which collectively accounted for an 11.3 million boe increase.

 

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Extensions and Discoveries

 

Extensions and discoveries during 2015 amounted to 24 million boe, which is comprised of 22 million boe of extensions of proved acreage and 2 million boe from newly discovered fields and reservoirs. The newly discovered fields in Colombia corresponded to two fields, Aullador and Lisama Norte. New reservoirs were discovered in Rex, Terecay and Vigia Sur. The extensions of proved acreage resulted mainly from activities in new proved areas in five fields (Castilla, Chichimene, San Roque, Ocelote and Yarigui), which accounted for 19 million boe of the total of 22 million boe from extensions of proved acreage. The remaining 3 million boe corresponds to smaller changes in several other fields.

 

Purchases & Sales

 

In 2015, we neither purchased nor sold any participation in producing oil or gas properties.

 

Development of reserves

 

As of December 31, 2015, our total proved undeveloped oil and gas reserves amounted to 379 million boe, 54% of which are related to the Castilla, Pauto, and Rubiales fields in Colombia which have continuous development activities. The Caño Sureste, Quifa, and Tibú fields collectively account 16% of total proved undeveloped oil and gas reserves with the remaining 30% from several other fields.

 

Our proved undeveloped reserves represent 21% of our total proved reserves.

 

The company’s year-end development plans are consistent with SEC guidelines for the development of proved undeveloped reserves within five years.

 

The following table reflects the developed and undeveloped proved reserves estimates through the past three fiscal years.

 

Table 31 – Developed and Undeveloped Proved Reserves

 

Proved Reserves as of December 31,  Oil   NGL   Gas   Total 
   Mmbls   Mmbls   Bcf   Mmboe 
2015 proved reserves                    
Developed   858    55    3,176    1,470 
Undeveloped   308    18    303    379 
2014 proved reserves                    
Developed   979    63    3,284    1,618 
Undeveloped   405    18    245    466 
2013 proved reserves                    
Developed   880    53    2,663    1,400 
Undeveloped   497    4    405    572 

 

Of the total amount of proved undeveloped reserves that Ecopetrol had at the end of 2014 (466 million boe), we converted approximately 76 million boe, or 16%, to proved developed reserves during 2015, primarily associated with the development of crude oil projects through drilling and workovers in the Castilla, Rubiales, Tibú, Chichimene, Yarigui – Cantagallo, Pauto, Ocelote, and Provincia, fields. These projects accounted for approximately 82% of the total conversion while the remaining 18% is associated with development execution in other fields such as the Moriche, Bonanza, and Pauto fields, among others. The amount of investments made during 2015 to convert proved undeveloped reserves to proved developed reserves was US$1,322 million.

  

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Changes in Undeveloped Proved Reserves

 

The following table reflects the main changes in undeveloped proved reserves during 2015.

 

Table 32 – Changes in Undeveloped Proved Reserves in 2015

 

Consolidated Companies

(million barrels oil equivalent)

    
Revisions of previous estimates   (23)
Improved recovery   9 
Extensions and discoveries   4 
Proved Undeveloped converted to Proved Developed   (76)
Net change in unproved reserves   (87)

 

 

The conversion rate used is 5,700 standard cubic feet = 1 barrel of oil equivalent.

 

Reserve Estimation Process

 

Ecopetrol’s reserves process is supervised and coordinated by the Corporate Reserves Director, a highly experienced geologist and engineer, who reports to the Chief Financial Officer. The reserves audit group is comprised of reserves coordinators who are geologist and petroleum engineers, each with more than 10 years of experience in reservoir characterization, field development, estimation and reporting of reserves and who have supervision and supporting responsibilities over the professionals involved in the estimation and reporting process.

 

Reserves are first estimated internally, supervised and coordinated by the Corporate Manager of Reservoirs, a geologist who holds a Master’s degree in geology and has more than 20 years of experience in projects associated with reservoir characterization and development, estimation, and reporting of reserves. The employees involved in the reserves process meet the Society of Petroleum Engineers qualifications for reserves estimators. Internally estimated reserves are submitted to an external audit process, which was conducted by the external engineers (Ryder Scott and DeGolyer and MacNaughton). According to our corporate policy, we report the reserves values obtained from the external engineers, even if they are lower than our internal estimated reserves.

 

The reserves estimation process ends when the Corporate Reserves Director consolidates the results and presents them to the Reserves Committee, which is composed of the Chief Financial Officer and the Vice-President of Development and Production. Results are presented to the Audit Committee of the Board of Directors and finally approved by the Board of Directors.

 

Petroleum engineering consultants DeGolyer and MacNaughton and Ryder Scott have audited Ecopetrol’s proved reserves as of December 31, 2015. These external engineers audited 99% of our estimated net proved reserves. The reserves reports of the external engineers are included as exhibits to this annual report. The external engineers DeGolyer and MacNaughton, Ryder Scott audited 99% of our estimated net proved reserves for the year ended December 31, 2014 and DeGolyer and MacNaughton, Ryder Scott and Gaffney and Cline audited 99% of our estimated net proved reserves for the year ended December 31, 2013.

 

Ecopetrol uses deterministic methods that are commonly used internationally to estimate reserves. These methods have some uncertainty with respect to degradation, and thus, the estimates should not be interpreted as being exact amounts. However, the technology used to estimate reserves is considered reliable. The majority of the producing proved reserves were estimated by applying appropriate decline curves or other performance relationships. In analyzing decline curves, reserves were estimated by calculating economic limits that are based on current economic conditions. In certain cases, where the methods previously employed could not be used, reserves were estimated by analogy with similar reserves for which more complete data was available.

 

Estimates of reserves were prepared by geological and engineering standard methods commonly used in the oil and gas industry. The method or combination of methods used in the analysis of each reserve was adopted from experience analogy reserves, including information on the stage of development, quality and completeness of basic data and production history.

 

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The following table reflects the estimated proved reserves of oil and gas as of December 31, 2013 through 2015, and the changes therein.

 

Table 33 – Estimated Proved Reserves of Oil and Gas

 

Consolidated companies  Colombia   North
America
   South
America
excluding
Colombia
   Total 
   Net proved oil, NGL and gas reserves in mboe 
At December 31, 2013   1,934    17    21    1,972 
Revisions   264.7    1.7    4.0    270.4 
Purchase of Minerals   0.0    0.0    0.0    0.0 
Improved Recovery   34.1    0.0    0.0    34.1 
Extensions and discoveries   50.1    0.8    0.0    50.9 
Sales   0.0    0.0    0.0    0.0 
Production   (239.6)   (1.5)   (2.0)   (243.0)
At December 31, 2014   2,043    18    23    2,084 
Revisions   (14.8)   (2.8)   (7.1)   (24.7)
Purchase of Minerals   0.0    0.0    0.0    0.0 
Improved Recovery   15.8    0.0    0.0    15.8 
Extensions and discoveries   24.4    0.0    0.0    24.4 
Sales   0.0    0.0    0.0    0.0 
Production   (247.5)   (1.4)   (1.8)   (250.7)
At December 31, 2015   1,821    14    14    1,849 

 

For more information regarding the potential impacts of oil prices on our reserve estimates, see the sections Financial Review—Trend Analysis and Sensitivity Analysis and Risk Review—Risk Factors.

 

3.4.4Joint Venture and Other Contractual Arrangements

 

We conduct our exploration and production business through a variety of types of contractual arrangements with the Colombian government or third parties. Below is a general description of each type of contractual arrangement to which we were a party as of December 31, 2015:

 

Association Contract

 

The association contract was created by the Decree 2310 of 1974. Its purpose is the exploration of the area covered by the contract, and the exploitation of hydrocarbons found in that area. This type of contract, together with E&P contracts and Special Contracts (Casabe and La Cira) which are described below, are the most significant in terms of our production and proved reserves.

 

Under association contracts, the exploratory risk is assumed entirely by Ecopetrol S.A.’s contractual partner, the associate. If there is a discovery and Ecopetrol S.A. agrees that the relevant field is commercially viable, Ecopetrol S.A. will participate in the field’s development. A joint account will be created and Ecopetrol S.A. and the partner will participate in the expenses and investments in the proportions established in the contract. Ecopetrol S.A. will reimburse the direct exploratory expenses incurred by the contractual partner in the proportions established by the contract.

 

If Ecopetrol S.A. does not believe that the relevant field is commercially viable, the partner has the right to execute on its own all activities considered necessary for the field’s exploitation as a “sole risk operation”, and to be reimbursed for a defined percentage of all investments for such sole risk operation in accordance with the contract.

 

Every association contract provides for an executive committee that makes all technical, financial and operational decisions if Ecopetrol S.A. has agreed that a field is economically viable. All major decisions of this committee must be made unanimously by the parties.

 

The maximum term of an association contract is 28 years. The first six years of the contract is for the exploratory phase, and is extendible for 1 or 2 more years at the partner’s request. The remaining time is for the exploitation phase.

 

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Incremental Production Contract

 

We enter into incremental production contracts to obtain incremental hydrocarbon production beyond a base production curve that is established based on the proven reserves of a specific field or well. Under this type of arrangement, Ecopetrol S.A. owns 100% of the hydrocarbons defined by the base production curve. The incremental production (i.e. the hydrocarbon volume obtained beyond the basic production as a result of investment activities), will be owned by the parties to such incremental production contract in the proportions established by such contract.

 

The initial phase of an incremental production contract has a term of up to three years, in which the contractual partner executes an initial work program approved by Ecopetrol S.A. in order to gain the right (but not the obligation) to continue with the second phase. If Ecopetrol’s partner decides to continue with the project for the second phase (the complementary phase), it must inform Ecopetrol S.A. in writing no later than 90 days prior to the termination date of the initial phase and deliver a proposed development plan for each covered field. The second phase is the production phase and has a maximum term of 22 years minus the length of the initial phase.

 

Incremental production contracts provide for an executive committee that is responsible for taking all decisions in order to approve, control, and supervise all operations that take place during the duration of the contract. These contracts also provide for a steering committee, which is responsible for the supervision of the execution of the work programs, the annual budget, and other items.

 

Risk Production Contract for Discovered Undeveloped and Inactive Fields (First Round 2003)

 

We have entered into risk production contracts for discovered undeveloped fields to promote exploration by private companies of both undeveloped and inactive fields. Under these contracts, the contracting party assumes all costs and expenses for the development and operation of a field in exchange for a percentage interest in the fields’ production as specified in the contract. This type of contract has a ten-year term calculated as from its date of execution; one year for the evaluation period and a maximum of nine years for the development period. Some of these contracts have subsequently been extended beyond their original term.

 

Operation for Risk Production Contracts for Discovered Undeveloped and Inactive Fields (Second Round 2005)

 

The contracts awarded in the second round of undeveloped and inactive discovered fields are service contracts wherein services rendered are payable with a percentage of the production. Ecopetrol S.A. keeps all rights to explore and exploit hydrocarbons found in the area.

 

These contracts have a 10 year term, including an evaluation period of 8 months, within which the operator has to comply with a minimum commitment to conduct a technical evaluation of the field at its own risk.

 

The facilities built during the term of the contract, other than facilities associated with drilled wells, will be owned by the operator, who will remain responsible for it, even after contract ends. Only drilled wells become property of Ecopetrol S.A. upon the contract’s termination.

 

Risk Participation Contract

 

The purpose of this contract is the exploration of the contracted area, and the exploitation of the oil found in the contracted area. Unlike in the association contract, Ecopetrol S.A., shares exploratory risks and costs with the contractual partner, the associate, together with the oil produced, in the proportions established by the contract.

 

Risk participation contracts provide for an executive committee which is created upon the execution of the contract.

 

These contracts have 28 year terms, including an exploratory period of six years (which period is extendible under certain contracts for one or two years), after which the exploitation period commences.

 

Special Contracts

 

We are party to a Joint Venture Contract for Exploration and Exploitation of “La Cira-Infantas” Area; and a Services and Technical Collaboration Contract for the “Casabe” field.

 

 33 

 

 

Joint Venture Contract for Exploration and Exploitation of “La Cira-Infantas” Area

 

The contract between Ecopetrol S.A. and Occidental Andina LLC, executed on September 6th, 2005, has as purpose a joint collaboration between the parties with the goal of increasing the economic value of the La Cira Infantas field, by means of hydrocarbon exploration and production activities including, among others, an incremental production project to improve the recovery factor, process optimization, and exploratory activities.

 

Ecopetrol S.A. partially assigned its exploratory and production rights in the Contracted Area to Occidental Andina LLC. Ecopetrol S.A. provides financial resources and the preferential rights of use for the existing infrastructure in that zone and Occidental Andina LLC provides financial resources and the technical and operative experience in mature fields redevelopment projects and enhanced recovery technologies.

 

Ecopetrol S.A. is the operator, and on behalf of the parties is responsible for the conduction, execution and control, directly or via contractors, of the operational activities.

 

The contract’s term is divided in three phases. The first phase lasts 180 days, the second 730 days and the third up to the economical limit.

 

The incremental production, after deduction of the royalties, is owned 52% by Ecopetrol S.A. and 48% by Occidental Andina LLC. These same percentages apply to the participation in the operational and direct expenses. Adjustments to the participations for the benefit of Ecopetrol S.A. will occur if there are high production levels or high prices.

 

Services and Technical Collaboration Contract “Casabe”

 

The purpose of the contract executed between Ecopetrol S.A. and Schlumberger Surenco S.A. on April 26, 2004, is the evaluation, design and execution of work programs specifically with the purpose of increasing the value in the Casabe field, by means of development of activities to obtain incremental production, application of new technologies, application of techniques for deposits management and operational costs reduction. Ecopetrol S.A. is the operator and Schlumberger Surenco S.A. keeps the right of first option regarding the activities to be executed in the area of interest.

 

Both parties can invest in all the activities seeking to evaluate, obtain and incorporate incremental value in the area of interest. Such activities are developed directly by the parties or via contractors (Ecopetrol) or subcontractors (Schlumberger). Amounts expended pursuant to the contract are reimbursed depending on the incremental value (monthly valuation in USD of the results obtained from the execution of the work programs) created through the contract and the activities executed thereunder.

 

Both Ecopetrol S.A. and Schlumberger Surenco S.A. commit to assume full responsibility for damages and/or losses suffered by their respective personnel and goods in development of the contract, regardless of the cause. The maximum authority is the Management Committee.

 

The contract had an initial term of 10 years, and was amended several times to include an additional term of six years for which a new business was structured.

 

The National Hydrocarbons Agency (ANH) and its Contracts

 

The National Hydrocarbon Agency was created by Decree Law 1760 of 2003 and was given the authority to administer all national hydrocarbon reserves under contracts executed beginning on January 1, 2004 (Decree Law 1760 of 2003 states, “The Empresa Colombiana de Petróleos, Ecopetrol, is split, its organic structure is modified, and the Agencia Nacional de Hidrocarburos and the Sociedad Promotora de Energía de Colombia S.A. are created”). Prior to January 1, 2004, Ecopetrol S.A. had the authority to contract with third parties for the exploration and production of new areas. The creation of the ANH did not modify the rights or obligations of Ecopetrol or other parties with respect to contracts in existence at the time when ANH was created and Ecopetrol retains the authority to execute agreements with respect to all areas that it held as of January 1, 2004 when the ANH was created.

 

 34 

 

 

 

Below, we include a brief description of each type of contract that we have entered into with the ANH:

 

Technical Evaluation Agreement

 

This type of contract grants to the contractor the right to develop technical evaluation operations with operational autonomy at its own cost and risk, seeking to appraise the hydrocarbon potential, with the purpose of identifying the zones of prospective interest in the area by means of the execution of an exploratory program. The contractor has the option to request the conversion of a technical evaluation agreement (“Technical Evaluation Agreement” or “TEA”) into one or more E&P Contracts that cover the area of the TEA (or a portion thereof).

 

The contractor can conduct evaluation activities for terms that vary between 18, 24 and 36 months, depending on the terms of reference of the ANH’s bidding round.

 

E&P Contract

 

The ANH enters into concession contracts pursuant to which the Nation grants exploration and production rights, and receives royalties and taxes. In turn, the contractor provides 100% of the investment and expenses resources, and receives 100% of the production after royalties and taxes. The ANH has named this contract an “Exploration and Production Contract” (E&P Contract).

 

Pursuant to the first contractual model, the ANH only received a percentage of oil revenues in two cases: (i) when the international oil prices rose beyond a specified price, above which the ANH has a right to participate in a share of the increased revenues generated, or (ii) in the case of recognition of production rights in an extended contractual phase.

 

Under all E&P contracts executed since ANH’s 2008 bidding round, the ANH receives a percentage of the production from the beginning of the contract, and not only in the extension phase of the contract as mentioned in the previous paragraph, in addition to economic rights when the price of oil exceeds a reference price set in the contract (high price fee) and the superficiary canon.

 

E&P contracts have two phases: an exploration period, which term is six years counted from the effective date, renewable for two additional years, and a production period, which is, with respect to each production field, 24 years plus any extensions, which are counted from the date of declaration of commerciality of the corresponding field. The above-mentioned terms have been modified during ANH’s 2014 bidding round for unconventional and offshore reservoirs to an exploration period of nine years and a 30 years exploration period.

 

ANH and Ecopetrol Agreements (Convenios)

 

At the time of termination or extension of any association contract (executed by Ecopetrol S.A. before December 31, 2003), the rights over the production area and over the movable and immovable assets therein will continue to belong to Ecopetrol S.A. Pursuant to article 2 of Decree 2288 of 2004, which regulates Decree Law 1760 of 2003, Ecopetrol S.A. must execute an agreement with the ANH to regulate the exploration and exploitation terms and conditions of the relevant area, previously subject to an association contract.

 

Decree 2288 of 2004 also established that Ecopetrol S.A. would have to execute agreements with ANH covering fields directly operated by Ecopetrol S.A. Under these agreements ANH recognizes the exclusive right of Ecopetrol S.A. to explore and exploit the hydrocarbons property of the Nation that are obtained in the areas they cover, until resource depletion or until Ecopetrol S.A. returns the area to the Nation through the ANH.

 

These agreements also provide the conditions under which Ecopetrol S.A. is able to assign, partially or completely, its rights and duties thereunder to third parties.

 

3.5Transportation and Logistics

 

3.5.1Open Access Business Model

 

In October 2012, Ecopetrol transferred its direct interests in Ocensa, ODC, Oleoducto Bicentenario de Colombia S.A.S. (“Oleoducto Bicentenario”), ODL S.A. and Serviport S.A. to Cenit. On April 1, 2013, Ecopetrol S.A. transferred its hydrocarbon transport and logistics assets (crude oil and multipurpose pipelines and loading and unloading facilities) to Cenit, and Cenit started its operations as owner of the transportation and logistics infrastructure. On January 1, 2014 Ecopetrol transferred its port concessions and assets to Cenit.

 

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The purpose of Cenit is to serve the strategic transportation and logistical needs of the country’s oil and refined products industry. Furthermore, it is designed to strengthen and expand the network with high standards of industrial safety and reliability and to contribute to environmental preservation.

 

Cenit’s commitment is to introduce transparency, equal and open access as well as to increase the focus on customer service in the hydrocarbon transportation business. In line with this, Cenit undertook initiatives to better understand customer needs, quarterly client meetings and an annual satisfaction tracker.

 

This decision is a step forward in the growth of the industry, as well as a signal of transparent rules to the market, by separating Ecopetrol’s role as owner, planner, operator and user of transport systems. Cenit operates with an open model in which all interested parties have the possibility of accessing crude oil transportation capacity in Colombia.

 

Cenit contracts capacity for its pipelines to third parties, and oversees and manages transportation infrastructure projects. Cenit also takes the lead in finding and exploiting profitable transportation and logistics opportunities. Cenit’s responsibilities include commercial management, system planning and development, new businesses and third-party liability.

 

On April 1, 2013, Ecopetrol S.A. entered into a number of contracts with Cenit establishing their ongoing relationship. Pursuant to transportation and service agreements, Cenit provides Ecopetrol S.A. for a term of 30 years with hydrocarbon and refined products transportation, storage, loading and unloading and logistics services through the transportation assets transferred to it as an in-kind capitalization. Ecopetrol S.A. also entered into an operation and maintenance agreement with Cenit pursuant to which Ecopetrol S.A. is in charge of the operation and maintenance of the transportation assets for a term of 15 years. In return, Cenit will pay Ecopetrol S.A. a variable monthly payment for the services rendered. The companies also entered into a project management agreement, pursuant to which Ecopetrol S.A. provides project management services on market terms to Cenit for a term of 15 years.

 

In December 2014, Ecopetrol S.A. received authorization from the Colombian Superintendence of Ports to merge its wholly owned subsidiary EPI into Cenit. This merger action was completed on December 19, 2014, adding COP$1 billion in assets to Cenit. As a result, Cenit is now a direct wholly-owned subsidiary of Ecopetrol S.A.

 

3.5.1.1Transportation Activities

 

The transportation and logistics segment includes the transportation of crude oil, motor fuels, fuel oil and other refined products including diesel and biofuels. We conduct most of these activities through our wholly-owned subsidiary Cenit and Cenit’s subsidiaries.

 

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The map below shows the locations of the main transportation networks owned by our business partners and us.

 

Graph 6 – Map of Pipelines

 

 

 

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Graph 7 – Map of Multipurpose Pipeline

 

 

 

The table below sets forth the volumes of crude oil and refined products transported through the crude oil pipelines and multipurpose pipelines owned by us.

 

Table 34 – Volumes of Crude Oil and Refined Products Transported

 

   For the year ended December 31, 
   2015   2014   2013 
   (thousand bpd) 
Crude oil transport(1)   978    954    950 
Refined products transport(2)   254    251    237 
Total   1,232    1,205    1,187 

 

 

(1)The crude oil transported volumes correspond to the following systems: Ocensa Segment 3, ODC, Vasconia-Galan, Ayacucho-Galan, Ayacucho-Coveñas and Trasandino Pipeline.
(2)The pipelines transporting refined products include the following: Galan-Sebastopol, Galan-Salgar, Galan-Bucaramanga, Buenaventura-Yumbo and Cartagena-Baranoa.

 

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The volume of crude oil transported by the main Cenit systems and those of affiliates increased in 2015 by 2.5% compared to the previous year. This was mainly the result of higher volumes transported in the Caño Limón - Coveñas and Oleoducto Transandino systems due to the decline in the number of attacks against our infrastructure. Of the total volume of crude transported by oil pipeline, approximately 71% was Ecopetrol’s corporate group´s product.

 

The volume of refined products transported by Cenit increased by 1.2% in 2015 mainly due to the larger volume of naphtha (heavy crude diluent) transported in the Pozos Colorados – Galán and Galán – Apiay systems and to higher volumes being transported through the Galan – Bucaramanga system in response to increased demand in the region as a result of the closure of the Venezuela border. Of the total volume of refined products transported in refined product pipelines during the year, 23% belonged to Ecopetrol’s corporate group.

 

Transportation Capacity

 

During 2015, we increased the capacity of our primary and secondary oil pipelines and loading facilities due to projects carried out by Cenit and its subsidiaries. Our main crude oil pipeline systems’ operating capacity increased from 1,328,000 bpd in 2014 to 1,336,000 bpd in 2015.

 

Our main refined products pipeline systems increased from 457,300 bpd in 2014 to 529,000 bpd in 2015. The foregoing increase in capacity was primarily the result of the expansion in the Galan-Sebastopol and Pozos – Galan systems.

 

References to our crude oil transportation capacity in this annual report refer to the capacity of the pipelines that belong to Cenit and its subsidiaries to transport crude oil volumes either to the Barrancabermeja Refinery or to our export facilities. In addition, we have other feeder systems that transport oil volumes from producing facilities or other pumping stations to these main pipelines. References to our refined products transportation capacity refer to the capacity of pipelines that begin in the Galan and Cartagena station (Barrancabermeja and Cartagena Refineries).

 

3.5.1.2Pipelines

 

As of December 31, 2015, we, directly or indirectly with private sector participants, owned, operated and maintained an extensive network of crude oil and refined products pipelines connecting our own and third-party production centers, import facilities and terminals to refineries, major distribution points and export facilities in Colombia. Cenit directly owns 46% of the total crude oil pipeline shipping capacity in Colombia (according to calculations made by Cenit). When aggregated with the crude oil pipelines in which Cenit owns an interest, Cenit owns 79% of the oil pipeline shipping capacity in Colombia (according to calculations made by Cenit). By December 31, 2015, our network of crude oil and multipurpose pipelines was approximately 8,986 kilometers in length. The transportation network consists of approximately 5,269 kilometers of main crude oil pipeline networks connecting various fields to the Barrancabermeja refinery and Reficar, as well as to export facilities. We also own 3,717 kilometers of multipurpose pipelines for transportation of refined products from the Barrancabermeja Refinery and from Reficar to wholesale distribution points.

 

Out of the 5,269 kilometers of crude oil pipelines owned by us 3,029 kilometers of crude oil pipeline are wholly owned and 2,240 kilometers of crude oil pipeline is owned through non-wholly owned subsidiaries.

 

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The following table sets forth our main pipelines in which we own an indirect interest as of December 31, 2015.

 

Table 35 – Our Main Pipelines

 

Pipeline  Kilometers   Capacity
(kbpd)
   Product
Transported
  Origin  Destination  Indirect
Ownership
Percentage
 
Caño Limón-Coveñas   771    250   Crude Oil  Caño Limón  Coveñas   100.00%
Oleoducto de Alto Magdalena (OAM)   397    110   Crude Oil  Tenay  Vasconia   87.29%
Oleoducto de Colombia (ODC)   480    236   Crude Oil  Vasconia  Coveñas   73.00%
Oleoducto Central (Ocensa Segment 2)   836    616   Crude Oil  Cupiagua  Coveñas   72.65%
Oleoducto de los Llanos (ODL)   262    340   Crude Oil  East fields  Monterrey Cusiana   65.00%
Oleoducto Bicentenario de Colombia   230    110(1)  Crude Oil  Araguaney  Banadia   55.97%

 

 

(1)Represents the contractual crude oil transportation capacity for the project currently in operation.

 

As of December 31, 2015, we owned 66 stations: 32 located in crude oil pipelines, 30 in refined products pipelines, two in crude oil ports and two in refined product ports. As of December 31, 2015, we had a nominal storage capacity associated with the transportation network of 16 million barrels of crude oil and 4 million barrels of refined products. We also sell storage capacity to third parties in our Pozos Colorados, Tocancipa and Mansilla facilities and in the Coveñas port. We do not own any tankers.

 

Pipeline Projects

 

SAN FERNANDO – MONTERREY

 

The San Fernando – Monterrey project’s objectives include ensuring the ability to transport 390,000 bpd of diluted crude oil from the Chichimene and Castilla fields to the Monterrey pumping station, the reversion of the Monterrey – Araguaney pipeline to transport 53,000 bpd of crude oil and the transportation of 85,000 bpd of diluent (naptha) between the Apiay station and the Castilla and Chichimene fields.

 

The scope of the project includes the construction of a new 30” 171 km crude oil pipeline, a receipt, storage and pumping station, and the reversion/conversion of the existing pipeline of 16” between the Castilla II plant and the Apiay station in order to transport diluent (naptha) from the Apiay station to the Castilla II plant.

 

In 2015, we finished a loop increasing the capacity between Apiay and Monterrey to 300,000 bpd and continued the construction of the remaining activities of the project.

 

COSTA NORTE COLOMBIANA – GALÁN

 

The Costa Norte – Galán project’s objective is to increase the transportation capacity from 90,000 to 160,000 bpd in the Pozos – Galán system for the transportation of imported naptha of up to 100,000 bpd and refined products (motor fuels and oils and gasoline) of up to 60,000 bpd.

 

The scope of the first module of the project, designed to increase capacity by 130,000 bpd, involves the construction of new infrastructure and optimization of the existing infrastructure from Pozos Colorados to Galán; the main effort is the installation of new pumping units in the Pozos Colorados and Copey stations. The second module, designed to increase capacity by 30,000 bpd, includes the construction of two storage tanks in Pozos Colorados. We began construction of the first module in 2015 and completed the project during the first quarter of 2016.

 

MAGDALENA MEDIO 100

 

The Magdalena Medio 100 project’s main objectives include increasing the storage capacity in the Coveñas – Cenit terminal to 1,200,000 barrels and the transportation capacity of crude oil in the Ayacucho – Coveñas 16” system pipeline to 100,000 bpd. During 2015, we completed the construction of four tanks and increased storage capacity in Coveñas. The project to increase the transportation capacity of crude oil in the Ayacucho – Coveñas 16” system pipeline to 100,000 bpd is currently being evaluated.

 

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OCENSA (P135)

 

The OCENSA P135 project’s main objective is to increase the pipeline transportation capacity by 135,000 bpd starting in the first six months of 2016. The project involves improving the pumping system and increasing the storage capacity. We currently expect the project to be completed by June 2016.

 

OLEODUCTO AL PACIFICO SAS

 

Cenit is participating in the Oleoducto al Pacífico SAS, led by Enbridge, which will transport heavy crude oil to the eastern market. In 2015, the scope of work was focused on reviewing the business case for the development of the project, conducting advance prior consultations with communities along the rights of way, negotiating project governance matters and reviewing regulatory, commercial and technical issues.

 

Due to the environment of the oil industry and uncertain about future volume of oil production in Colombia, the project continuity is under revision and in a hold status.

 

TRANSPORTATION OF HIGHER VISCOSITY CRUDES

 

At the close of 2015, testing was conducted successfully on various systems and information was gathered to move ahead with the analyses to transport crudes with higher level of viscosity that will allow Ecopetrol to reduce dilution costs.

 

The main modifications will be made on: the Los Llanos Pipeline (ODL - Oleoducto de los Llanos; Rubiales – Cusiana), on OCENSA Segment I (Cusiana – Porvenir), Segments II & III (El Porvenir – Vasconia – Coveñas) and on the Colombia Pipeline (ODC – Oleoducto de Colombia). This project, combined with the expansion of capacity on Ocensa (P-135), will make it possible to transport higher viscosity crudes.

 

3.5.1.3Export and Import Facilities

 

We currently have concessions granted by the Nation for four export/import docks for crude oil and refined products: Coveñas, Tumaco, Pozos Colorados and Buenaventura. Our export capacity reached 1.14 million bpd for crude oil. Our import capacity of refined products reached 0.16 million bpd.

 

Our crude oil loading facilities can load tankers of up to 350,000 deadweight tonnage, or DWT. Adjacent to these loading facilities we also have crude oil storage facilities that are capable of storing 7.7 million barrels. Our docks used for import and export of refined products can load tankers of 70 thousand DWT. Additionally, these facilities have storage capacity of up to 1.2 million barrels.

 

3.5.2Other Transportation Facilities

 

We have entered into transportation agreements with tanker-truck and barge companies in order to transport crude oil from locations that do not have pipeline connections to refineries and export facilities. The volume of refined products that cannot be transported in pipelines or in tanker trucks because of capacity limitation is transported by barges. During 2015, 38 million barrels of crude oil and refined products were transported by tanker trucks and 7.6 million barrels of crude oil and refined products were transported by barges, specially using Rio Magdalena, connecting Barrancabermeja with Barranquilla and Cartagena.

 

3.5.3Vice-Presidency of Transportation and Logistics

 

Ecopetrol S.A., through its Vice-Presidency of Transportation and Logistics, operates Cenit’s pipelines pursuant to a contract with Cenit.  The Vice-Presidency of Transportation and Logistics focuses on maintaining the integrity of the transportation infrastructure by improving our operational risk model for transportation infrastructure with respect to weather conditions and damage caused by third parties, as well as deploying new technologies to monitor transportation infrastructure and its environment and to permit intervention in portions of the infrastructure where it is susceptible to incidents that could have severe consequences.

 

The Vice-Presidency of Transportation and Logistics now comprises four main areas: Operations and Maintenance, Comprehensive Transportation and Logistics Solutions, Asset Management, and Commercial and Customer Service.  All of these areas aim to accomplish their obligations to their customers:  Cenit, ODL, ODC, Ocensa and Oleoducto Bicentenario.

 

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During 2015, we met our customer satisfaction index goal, and we maintained our ISO 9001:2008, GP1000:2009, ISO 14001:2004 and OHSAS 18001:2007 certifications for all of our transportation processes.  We also attained the certification by the Oil Companies International Marine Forum, which provides standards for hydrocarbons reception, storage, dispatch by pipes and pipelines and the import and export facilities of our ports.

 

3.5.4Marketing of Transportation Services

 

Cenit and its subsidiaries’ main line of business is the crude oil pipeline transport (57% of revenues), followed by the refined products pipeline transport (29% of revenues) and ports and related services (8% of revenues).

 

Transportation contracts of crude oil may take several forms: ship or pay (payment for the availability of a fixed capacity in the system), ship and pay (payment for volumes actually transported) or spot. The main clients for the crude oil transportation business are Ecopetrol S.A., Pacific Rubiales Energy, Occidental de Colombia, Hocol, Mansarovar and Gran Tierra, who collectively represented 94% of this business segment’s revenues in 2015. Transportation services for crude oil provided to Ecopetrol S.A. represented 69% of this business segment’s crude oil transport revenues.

 

Cenit also transports refined products. The main client for this service is Ecopetrol S.A., which accounted for 37% of refined products pipeline transport revenues in 2015, principally due to the transport of naphtha. Cenit also has 15 other fuel wholesaler customers for whom it transports other refined products. Wholesalers representing most of the volume are Organizacion Terpel, ExxonMobil, Chevron Petroleum Company, Biocombustibles and Petrobras Colombia.

 

Cenit transports LPG for 16 clients, under written contracts. LPG transport represents less than 1% of Cenit’s revenue.

 

Deregulated businesses such as ports and crude loading facilities represent a smaller portion of Cenit’s revenue (8% in 2015). Clients for these businesses include some of the same parties for which Cenit provides crude oil and refined products transportation services.

 

3.6Refining and Petrochemicals

 

3.6.1Refining

 

Our main refineries are the Barrancabermeja Refinery, which Ecopetrol S.A. directly owns and operates, and a refinery in the Free Trade Zone in Cartagena that is operated by Reficar S.A., a wholly owned subsidiary of Ecopetrol S.A. Ecopetrol S.A. also owns and operates two other minor refineries – Orito and Apiay, but these are considered part of the exploration and production segment since the majority of the products produced by them are used by us.

 

Our refineries produce a full range of refined products, including gasoline, diesel, jet fuel, liquefied petroleum gas (LPG), and heavy fuel oils, among others.

 

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The following table sets forth our daily average installed and actual refinery capacity for each of the last three years:

 

Table 36 – Daily Average Installed and Actual Refinery Capacity

 

   For the year ended December 31, 
   2015   2014   2013 
   Capacity   Through-
put
   % Use   Capacity   Through-
put
   % Use   Capacity   Through-
put
   % Use 
   (bpd)   (bpd)       (bpd)   (bpd)       (bpd)   (bpd)     
Barrancabermeja   250,000    221,900    89%   250,000    226,900    91%   250,000    214,845    86%
Reficar(1)   165,000    10,428    6%   80,000    10,420    13%   80,000    66,314    83%
Apiay(2)   2,500    1,604    64%   2,500    1,380    55%   2,500    1,303    52%
Orito(2)   2,500    929    37%   2,500    1,784    71%   2,500    900    36%
Total   420,000    234,861    56%   335,000    240,484    72%   335,000    283,362    85%

 

 

(1)Reficar operations were shut down in March 2014 for the expansion and modernization plan. The new crude unit began start-up process in October 2015. As of the date of this annual report, the construction of the entire expansion and modernization project has been completed.

(2)Apiay and Orito are considered to be part of the exploration and production segment, not the refining segment, and the majority of products produced by them are used by us (self-consumption).

 

3.6.1.1Barrancabermeja Refinery

 

At the Barrancabermeja Refinery, we produce a variety of fuels, such as regular and premium unleaded gasoline, diesel fuel, kerosene, jet fuel, aviation fuel, LPG, fuel oil and sulfur. We also produce petrochemicals and industrial products, including paraffin waxes, lube base oils, low-density polyethylene, aromatics, asphalts, alkylates, cyclohexane and aliphatic solvents, as well as refinery grade propylene. The Barrancabermeja Refinery supplies 75.6% of the fuels consumed in Colombia according to internal calculations based on the Barrancabermeja refinery’s production and Colombia´s fuels consumption reported by the Ministry of Finance.

 

The following table sets forth the production of refined products of Barrancabermeja for the periods indicated.

 

Table 37 – Production of Refined Products of Barrancabermeja

 

   For the year ended December 31, 
   2015   2014   2013 
   (bpd) 
LPG, Propylene and Butane   13,623    13,834    13,572 
Gasoline Fuels and Naphtha   59,487    68,914    67,592 
Diesel   46,212    44,273    45,179 
Jet Fuel and Kerosene   22,388    23,227    19,546 
Fuel Oil   64,306    66,928    58,852 
Lube Base Oils and Waxes   521    1,103    1,468 
Aromatics and Solvents   3,197    2,640    2,632 
Asphalts and Aromatic Tar   9,519    7,501    6,174 
Polyethylene, Sulfur and Sulfuric Acid   1,318    1,094    1,118 
Total   220,571    229,515    216,133 
Difference between Inventory of Intermediate Products   142    (640)   538 
Total Production   220,713    228,875    216,671 

 

In 2015, total production in the Barrancabermeja Refinery decreased 3.5% from 228,875 bpd in 2014 to 220,713 bpd in 2015 due to the scheduled maintenance of one of its crude refining units in August 2015.

 

The gross refining margin increased from US$14.60 per barrel in 2014 to US$16.80 per barrel in 2015, primarily due to: 1) an increase in the yields achieved by medium distillates, 2) an increase in the prices of LPG, Gasoline and Fuel Oil, and 3) the implementation of operating initiatives to increase the value of LPG and residual streams.

 

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The average conversion ratio for Barrancabermeja Refinery was 73.5% in 2015 and 71.4% in 2014. This increase in the conversion ratio was primarily caused by more efficient operations by the crude units and higher throughput in the cracking units.

 

During 2015, the Barrancabermeja Refinery delivered 29.82 mboepd of low sulfur gasoline (less than 300 parts per million sulfur content) and 36.35 mboepd of low sulfur diesel (less than 50 parts per million sulfur content) to meet existing fuel quality standards while partially satisfying rising domestic demand, which was supplemented with imports. In order to do so, in 2015 we decreased imports of ultra-low sulfur diesel by 2 mboepd from the 2014 level and increased imports of gasoline by 17.1 mbpd from the 2014 level.

 

Natural gas from the Ballena terminal located in the La Guajira fields is transported to the Barrancabermeja Refinery pursuant to a natural gas transportation agreement entered into on October 1, 2008, between Ecopetrol and TGI for the transportation of 116,500 thousand cfpd from December 1, 2012 to December 31, 2020. Pursuant to the terms of the agreement, we pay to TGI a regulated transportation tariff composed of a fixed fee, variable fee depending on transported volumes and an administration, operation and maintenance fee. Payments for transported volume are quoted in U.S. dollars and settled in Colombian Pesos. During 2015, we paid COP$153.3 billion to TGI under the agreement.

 

3.6.1.2Reficar

 

The following table sets forth the production of refined products of Reficar for the periods indicated.

 

Table 38 – Production of Refined Products of Reficar

 

  

For the year ended December 31,(1)

 
   2015   2014   2013 
   (bpd) 
LPG, Propylene and Butane   0    0    3,264 
Motor Fuels   1,558    1,997    19,679 
Diesel   2,282    2,254    15,669 
Jet Fuel and Kerosene   1,202    812    6,090 
Fuel Oil   2,826    3,352    15,468 
Aromatic Tar   0    0    691 
Other Products   0    0    27 
Total   7,868    8,415    60,888 
Difference between Inventory of Intermediate Products   2,476    1,896    6,613 
Total Production   10,344    10,311    67,502 

 

 

(1)The table shows the entire production of Reficar. The refinery was shut down in March 2014 and began the start-up process in October of 2015.

 

In connection with its expansion and modernization project, Reficar was shut down for most of the year 2015. Following the planned start-up of its units, Reficar operated at half capacity from November to December of 2015.

 

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The following tables set forth the imports and sales of refined products of Reficar for the periods indicated.

 

Table 39 – Imports and Sales of Refined Products of Reficar

 

   For the year ended December 31, 
   2015   2014   2013 
   (bpd) 
Imports               
Motor Fuels   15,112    11,460    5,742 
Diesel   21,979    18,334    17,490 
Jet Fuel and Kerosene   4,384    3,419    0 
Total Imports   41,475    33,213    23,232 

 

   For the year ended December 31, 
   2015   2014   2013 
   (bpd) 
Sales               
Motor Fuels   16,101    14,154    21,561 
Diesel   22,692    21,942    34,548 
Jet Fuel and Kerosene   5,012    3,681    5,468 
Fuel Oil   2,066    4,335    15,014 
Other Products   2,281    2,194    11,448 
Total Sales   48,152    46,306    88,039 

 

During 2015, Reficar imported products to cover the North Coast sales demand. In connection with the startup of the crude oil unit in October 2015, Reficar also imported fuel oil, virgin naphtha and butanes in order to fulfill local demand. We expect to increase the competitiveness and profitability of Reficar through the modernization of its facilities and processes, and the improvement of its reliability based on the much higher automation capability. We currently expect to complete the modernization process and reach the normal operating condition during the second quarter of 2016.

 

Upon full completion of the project and once all the performance tests are completed, Reficar will have the capacity to processing between 150 - 165 thousand barrels of oil per day. Further we expect to improve refining margins by processing lower cost heavy and acid crude oils, taking advantage of the current buyer´s market. We have also started processing foreign crudes for the first time, to identify the best crude blend for the new facility in order to improve our conversion ratio, and producing a higher quality slate of products. We also expect to reduce the sulfur content in gasoline and diesel fuel, thus complying with current national and international fuel standards without the need to blend imported ultra low sulfur diesel. Being able to produce better quality fuels will also allow us to explore new markets abroad.

 

On December 30, 2011, with the approval from the Ministry of Finance and Public Credit, Reficar executed a US$3.5 billion project finance to partially fund the expansion and modernization of the refinery in Cartagena, loans with tenures of 14 and 16 years for Commercial Banks and Export Credit Agency Facilities, respectively. The aggregate amount drawn under these finance agreements as of December 31, 2015 totaled US$3,496.5 million. As of December 31, 2015, the principal amount owed to the senior lenders under these finance agreements was US$3,065.3 million. Interest payments during 2014 and 2015 were US$96 million and US$92 million, respectively.

 

As part of the project finance structure, Ecopetrol S.A. entered into a Construction Support Agreement (the “Construction Support Agreement”) and a Debt Service Guarantee Agreement (the “Debt Service Guarantee Agreement”) to support certain obligations of Reficar. Pursuant to the terms of the Construction Support Agreement, Ecopetrol S.A. agrees to support up to the completion date, any additional costs, expenses or delays incurred during the construction phase of the expansion and modernization of the refinery in Cartagena.

 

During 2015, the requested amount by Reficar under the Construction Support Agreement was US$722 million, which was contributed by means of capital injections.

 

By means of the Debt Service Guarantee Agreement, Ecopetrol S.A. provides a liquidity mechanism, allowing Reficar to pay its debt service in situations in which there are liquidity shortfalls, as well as being a mechanism to exit the project finance by transferring its debt at the level of Ecopetrol S.A. in case of the occurrence of a Mandatory Debt Assumption Event as defined in the credit agreement.

 

During 2015, the requested amount by Reficar under the Debt Service Guarantee Agreement was US$378 million, which was contributed by means of capital injections of US$193 million to cover the debt service in the first half of 2015 and US$185 to cover the debt service in the second half of 2015.

 

In total, the Reficar modernization project has had capital expenditure needs of US$8,016 million and interest and commission payment needs of US$424 million during construction, for a total of US$8,440 million. This amount has been financed as follows:

 

·An initial contribution of US$1,503 million from Ecopetrol which was received from 2008 to 2011;

 

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·US$3,496.5 million from the project finance loans described above; and

 

·Contributions of US$3,441 million from Ecopetrol through the Construction Support Agreement described above.

 

In addition and in order to cover the existing refinery needs for 2015, Reficar requested an additional capital injection from Ecopetrol S.A. of US$289 million, which was granted. Further, in order to finance the requirements of the startup process of the new refinery, Ecopetrol S.A. provided Reficar with an additional capital injection of US$194 million in 2015. As a result, total capital injections during 2015 from Ecopetrol S.A. to Reficar reached an amount of US$1,583 million.

 

3.6.2Petrochemicals and Other Products

 

We own and operate four petrochemical plants and one paraffin and lube plant located within the Barrancabermeja Refinery. In 2015, we produced 44,161 tons per year of low-density polyethylene, an increase of 42% compared to the production of 31,051 tons per year in 2014. This increase was due primarily to the recovery of the Turbo expander unit, which resumed operations in August 2015 and supplied a greater amount of feedstock (ethylene) to polyethylene plants. We produced 2,259 mboepd of aromatics (benzene, toluene, xylene, orthoxylene, heavy aromatics and cyclohexane), a 113% increase as compared with the production of 1,118 mboepd of aromatics in 2014. The growth was mainly the result of the stability of the unit during 2015 as compared to the scheduled turnaround of the unit in 2014.

 

3.6.2.1Polipropileno del Caribe S.A.

 

During 2015, Propilco production totaled 434 thousand tons of petrochemical products, an 11.5% increase compared to the 390 thousand tons produced in 2014, due to higher sales volumes explained by greater competitiveness and lower availability of Asian competitors in the local market. The total contribution margin in 2015 (including the contribution of polypropylene, polyethylene and masterbatches) was 24% higher than in 2014, an increase from US$239.00 per ton in 2014 to US$297.00 per ton in 2015. The increase in contribution margin was primarily due to the execution of a new commercial strategy focused on differentiation and value-added products and services.

 

Table 40 – Operating Capacity of Propilco

 

   For the year ended December 31, 
   2015   2014   2013 
   (Metric Tons) 
Average capacity   470,000    475,000    475,000 
Throughput   434,484    389,604    395,869 
% Use   92%   82%   83%

 

3.6.2.2Biofuels

 

We have investments in two biofuels companies: (i) Bioenergy S.A., in which we own 96.2% of the shares, currently advancing on the construction of an ethanol plant with theoretical capacity of 480,000 liters / day, and (ii) Ecodiesel S.A., in which we own 50% of the shares, currently in operations with a theoretical capacity of 100,000 tons per year of biodiesel.

 

3.6.3Marketing and Supply of Refined Products

 

We are the main producer and supplier of refined products in Colombia. We market a full range of refined and feed-stock products including regular and high octane gasoline, diesel fuel, jet fuel, natural gas and petrochemical products, among others.

 

In 2015, Ecopetrol sold 1,005.9 mboepd, out of which 362.7 mboepd represented sales of products (36.1%) including refined products like liquid fuels, LPG and fuel oil, petrochemicals and industrials.

 

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The sales of products grew 13.6 mboepd, an increase of 3.9% compared with 2014. Out of this, fuel domestic sales increased by 22.5 mboepd, 8.4% more, mainly due to: (i) the rise in demand for gasoline and diesel resulting from the increase of number of vehicles in Colombia, (ii) the closure of Colombia’s border with Venezuela as customers in that area shifted their demand to Ecopetrol and (iii) a higher consumption of thermal electricity during late 2015 due to warmer weather caused by the “El Niño” climate phenomenon, among other factors. Exports of fuels decreased by 8.9 mboepd, a reduction of 10.8% as compared to 2014, due to lower fuel oil production in the Barrancabermeja Refinery and decreased exports by Reficar. This reduction was partially offset by an increase in Propilco’s exports of close to 1.1 mboepd in 2015 as compared to 2014.

 

In addition, local sales of petrochemicals (included in domestic sales of products) remained stable over the previous year (21.6 mboepd in 2015 compared with 20.2 mboepd in 2014), due to an increase in asphalt and aromatic solvents sales by Ecopetrol S.A. and an increase in Propilco ´s sales.

 

Local sales of regular gasoline, LPG, jet fuel and diesel fuel are subject to government price regulation with reference to international benchmarks.

 

The CREG, has the responsibility of setting forth regulations for the control and surveillance of the activities of refining, importation, storage, distribution and transportation of liquid fuels derived from petroleum. Until 2011, according to Decree 4130, this function was performed by the Ministry of Mines and Energy.

 

The responsibilities assigned to the CREG are:

 

·Setting the prices of petroleum products along the entire chain of production and distribution (except for regular gasoline, diesel and biofuels, the retail prices for which are set by the Ministry of Mines and Energy)

 

·Regulating the activities of refining, importation, storage, distribution and transportation of liquid fuels derived from petroleum.

 

·Regulate tariffs for transportation of liquid fuels. 

 

·Regulating LPG, including LPG prices.

 

3.7Research and Development; Intellectual Property

 

The Vice-Presidency of Technology and Innovation was created in March 2012 to add value to our business segments through innovation and the development of technology, knowledge management and a competitive advantage. The Vice-Presidency of Technology oversees three directorates: the Colombian Petroleum Institute, the Directorate of Information Technology and the new Strategic Directorate of Knowledge, Innovation and Technology.

 

Our applied scientific research and technology development activities are conducted by the Colombian Petroleum Institute. The focus in technology development is on designing high value-add products and solutions for us and the Colombian oil industry. The scope of the Colombian Petroleum Institute activities covers all of our value chain segments: exploration, production, refining, transportation and commercialization, as well as environmental sustainability, asset integrity and automation. Our total budget in science and technology during 2015 was approximately US$75 million. Each year we present to the Colombian Institute for the Development of Science and Technology (Instituto Colombiano para el Desarrollo de la Ciencia y la Tecnología, or COLCIENCIAS) our research, technology development projects and innovation initiatives in order to obtain certification for our science and technology investments. COLCIENCIAS certifies science and technology investments, which are deductible from income tax upon execution; and we take advantage of that tax benefit. In 2015, we obtained US$28 million in tax benefits from our science and technology investments that COLCIENCIAS certified in previous years.

 

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Our intellectual capital is preserved through a technological value-generation process and an intellectual property protection process, which includes the consolidation of trade secrets, patents, copyrights, trademarks and publications in specialized journals. We filed 188 patent applications in the last ten years, including 15 in 2015, for new technologies related to equipment and processes for enhanced oil recovery, in-situ combustion, artificial lift system processes, heavy oil acidity reduction, specialized coatings for transportation pipelines and planning of refinery processes, among others. In 2015, Ecopetrol filed its first trade secret, which is related to palynology and biostratigraphy-related information from Colombian basins and formations.

 

We currently hold 70 patents in Colombia, the United States, China, Mexico, Russia, Peru, Venezuela, Ecuador, Brazil, Nigeria, Korea and Indonesia. In 2015, we were granted 10 new patents and 63 copyrights. We also have 33 trademarks.

 

In 2015, five technological products developed by Ecopetrol were licensed to national and multi-national companies for marketing and after-sales support. To date, we have licensed a total of 16 technologies. These licensed technological products have been tested and successfully used in our organization to solve problems related to refining, production and transportation of hydrocarbons, and some have potential uses in other industries.

 

3.8Applicable Laws and Regulations

 

3.8.1Principal Regulatory Bodies

 

The main authorities that regulate our activities in Colombia are: the Ministry of Mines and Energy, the National Hydrocarbons Agency (ANH), the Energy and Gas Regulatory Commission (CREG), the Ministry of Environment and Sustainable Development, and the National Authority on Environmental Licensing (ANLA).

 

Ministry of Mines and Energy

 

The Ministry of Mines and Energy is responsible for managing and regulating Colombia’s non-renewable natural resources, ensuring their optimal use by defining and adopting national policies regarding exploration, production, transportation, refining, distribution and export of minerals and hydrocarbons.

 

National Hydrocarbons Agency – ANH

 

The ANH’s purpose is to manage the hydrocarbon reserves owned by the Nation through the design, promotion and negotiation of the exploration and production agreements in areas where hydrocarbons may be found that are not (i) subject to joint ventures executed before December 31, 2003 and still in force or (ii) directly operated by Ecopetrol S.A.

 

The ANH is also responsible for creating and maintaining attractive conditions for investments in the hydrocarbon sector and for designing bidding rounds for exploration blocks. Furthermore, the ANH is responsible for managing all the royalties paid by oil and gas producers in Colombia.

 

From 1974 until the issuance of Decree Law 1760 of 2003, the role that the ANH currently has as administrator of the Nation’s hydrocarbon resources was performed by Ecopetrol. As part of this public function, Ecopetrol had the authority to assign areas for exploration and to execute various types of contracts with third parties, with the exception of concession contracts. As from 2003, and with the issuance of Decree Law 1760 of 2003, the public function of administration of the Nation’s hydrocarbon resources was assigned to the ANH, and Ecopetrol transferred all exploratory areas to the ANH, with certain exceptions as indicated below.

 

The aforementioned Decree Law provided that Ecopetrol would continue administrating association contracts executed by Ecopetrol with third parties before the date of entry into force of Decree Law 1760. It also provided that Ecopetrol would keep the exploration and productions rights to all areas that it was operating directly and/or subject to other service contracts or incremental production contracts different to association contracts. Therefore, the reform enacted in 2003 created a transitional regime by virtue of which Ecopetrol kept the administration of association contracts. This administration authority was confirmed by Decrees 4137 of 2011, and 714 of 2012 wherein it is clearly stated that ANH does not administrate association contracts.

 

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Energy and Gas Regulatory Commission – CREG

 

The CREG, a special administrative unit of the Ministry of Mines and Energy, is responsible for establishing the standards for the exploitation and use of energy and regulating the domestic utilities of electricity and fuel gas (liquefied petroleum gas and natural gas). CREG is also responsible for fostering the development of the energy services industry, promoting competition and responding to consumer and industry needs. It sets prices of petroleum products, except for regular motor gasoline, diesel and biofuels, along the entire chain of production and distribution; determines criteria and methodology for calculating the price of fuel; carries out the studies required for the determination and pricing of natural gas destined for use as automotive fuel and other purposes inherent in the commercialization of the same; regulates the rates in Colombian Pesos per kilometer/gallon for transportation through the pipeline system; and regulates the activities of refining, import, storage, distribution and transportation of liquid fuels derived from petroleum.

 

Ministry of Environment and Sustainable Development

 

The Ministry of Environment and Sustainable Development has among its main functions the issuance of public policies regarding the use and exploitation of natural resources and the regulation of national environmental laws.

 

The Ministry of Environment and Sustainable Development defines the procedures and guidelines that regulate the issuance of environmental licenses and permits necessary for the development of the following activities: production, exploration, extraction, transportation and refining.

 

National Authority on Environmental Licensing (ANLA)

 

The National Authority on Environmental Licensing issues environmental licenses and permits required for hydrocarbon-related activities. The ANLA is an administrative unit of the Ministry of Environment and Sustainable Development. Additionally, the National Authority on Environmental Licensing constantly monitors license compliance, handles complaints and grievances presented by local communities, and has overall responsibility for regulating the procedures by which the environmental permits needed for Ecopetrol’s operation are issued and enforced. The ANLA also has power to impose preventive measures and/or sanctions to offenders of environmental laws and regulations.

 

Other Authorities Related to Environmental Matters

 

Regional Autonomous Corporations (Corporaciones Autónomas Regionales)

 

The regional autonomous corporations are the entities responsible for the administration of natural resources located within their respective jurisdictions. Although they do not have legal jurisdiction over issues related to the oil industry, they are responsible for granting permits for the use of certain natural resources, such as water, air and soil necessary for the development of our activities.

 

Ministry of Internal Affairs

 

The Ministry of Internal Affairs is responsible for certifying the existence of ethnic communities, such as Aboriginal, Afro-Colombian and “Raizales”, a Colombian legal term that refers to the people born in the San Andrés Island archipelago. Such certification is intended to establish the presence of ethnic communities in areas in which seismic, exploration, extraction, transportation and refining activities are intended to take place. In addition, the Ministry has the ability to issue general guidelines that must be fulfilled through consultation with the relevant communities and which are necessary for the viability of any work, project or activity intended to be done in the territories of those communities.

 

3.8.2Regulation of Exploration and Production Activities

 

3.8.2.1Business Regulation

 

Pursuant to the Colombian Constitution, the Nation is the exclusive owner of all hydrocarbon resources located in Colombia and has full authority to determine the rights to be held and royalties or compensation to be paid by investors for the exploration or production of any hydrocarbon reserves. The Ministry of Mines and Energy and the ANH are the authorities responsible for regulating all activities related to the exploration and production of hydrocarbons in Colombia.

 

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Decree Law 1056 of 1953 (the Petroleum Code, or Código de Petróleos) declares that the hydrocarbon industry and its activities of exploration, exploitation, refinement, transportation are of public interest, which means that, in the interest of the hydrocarbon industry, the Colombian government may order necessary expropriations in order to develop such industry. The hydrocarbon industry is under governmental supervision and control, regulated mainly by the Ministry of Mines and Energy and the ANH.

 

Ministry of Mines and Energy Resolution 18 1495 of 2009, as amended by Resolution 40048 of 2015, establishes a series of regulations regarding hydrocarbon exploration and production.

 

Ministry of Mines and Energy Resolution 18 0742 of 2012, as amended by Resolution 90341 of 2014, included a series of technical regulations for unconventional hydrocarbon resources, including the procedures for advancing the exploration and exploitation of unconventional reserves. It also establishes the types of wells and their classification as well as the fulfillment of those minimum (drilling and abandoning) conditions, necessary to initiate or perform E&P activities. Furthermore, it contemplates the applicable procedure to resolve disputes between mining sector and the oil and gas sector, regarding the coexistence of their rights in some specific projects.

 

On May 26, 2015, the Ministry of Mines and Energy issued Decree 1073 which compiles the majority of Colombian decrees and regulations in force regarding the administrative sector of mines and energy.

 

Agreement (Acuerdo, a type of regulation) 004 of 2012, as issued by the ANH, amends Agreement 008 of 2004 and sets forth the rules governing the award of exploration and production areas and the execution of contracts.

 

Agreement 003 of 2014, as issued by the ANH, complements Agreement 004 of 2012 by setting forth the contractual framework for the carrying out of activities in unconventional reservoirs, the procurement regulations for the exploration and exploitation of unconventional fields and the procurement process for the awarding of hydrocarbon exploration and exploitation areas.

 

Agreement 002 of 2015, as issued by the ANH, amends Agreement 004 of 2012 and sets forth the initial rules and measures the Government can take to mitigate the adverse effects of the decline of international oil prices. The main measures established by this agreement are the following:

 

(i)The extension of terms and deadlines for the execution of activities related to investments in exploration and evaluation phases and for the declaration of commercial discoveries; and

 

(ii)The establishment of procedures to transfer investments in exploration programs between allocated areas.

 

Agreement 003 of 2015, as issued by the ANH, modifies and also amends Agreement 004 of 2012, and provides certain rules and measures the Government can take to mitigate the adverse effects of the decline of international oil prices. This agreement permits performance guarantees required under E&P contracts to be reduced in the same amount as the works actually performed during the term of the respective phase.

 

Agreement 004 of 2015, as issued by the ANH, also amends Agreement 004 of 2012, and provides certain rules and measures for the Government to mitigate the adverse effects of the decline of international oil prices. This agreement allows contractors to attribute additional activities carried out under a TEA to commitments under the first phase of an E&P contract.

 

3.8.2.1.1.Environmental Licensing and Prior Consultation

 

Law 99 of 1993 and other environmental regulations, such as particularly Decree 1076 of 2015, impose on companies, including oil and gas companies, the obligation to obtain an environmental license prior to undertaking any activity that may result in the serious deterioration of renewable natural resources, or that have the capacity of materially modifying the physical environment.

 

The National Authority on Environmental Licensing (ANLA), created by means of Decree 3573 of 2011, is the entity responsible for evaluating the applications and issuing the environmental licenses for oil & gas-related activities, as well as surveilling and overseeing all hydrocarbons projects and monitoring the environmental compliance of such activities.

 

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If the projects or activities could have a direct impact over the territories or the interests of indigenous, Afro-Colombian or Raizal communities, the Colombian Constitution provides that the companies developing such projects or activities must undertake a consultancy process with those communities before initiating such projects or activities. This consultation procedure is a pre-requisite for obtaining the required environmental licenses.

 

In addition, the Colombian Constitution and laws establish that, as part of the public participation mechanisms, Colombian individuals may request information regarding the activities of the project and their potential impacts. They may also request to undertake an environmental hearing so as to obtain information the project.

 

On May 26, 2015, the Ministry of Environment and Sustainable Development issued Decree 1076, which compiles the majority of Colombian regulations in force regarding environment and sustainable development.

 

The environmental licensing process encompasses all of the necessary permits, authorizations, concessions and other control instruments necessary under Colombian environmental law to undertake a project or activity that may result in the serious deterioration of renewable natural resources, or that have the capacity of materially modifying the physical environment. The licensing process establishes specific conditions under which the beneficiary of the license may undertake such project or activity. This process begins when the company files an Environmental Impact Study (EIA) related to the project with the ANLA. The licensing process includes an application for the use of natural renewable resources (water, soil and air), the filing of an EIA and a plan to prevent, mitigate, correct and compensate for any activity that may harm the environment, known as the Environmental Management Plan (PMA).

 

A new environmental licensing process came into force in Colombia on January 1, 2015 as a result of the enactment of Decree 2041 of 2014, which now is compiled by Decree 1076 of May 26 2015, repealing the licensing process defined in decree 2820 of 2010. According to the regulation currently in effect, the procedure to obtain an environmental license shall not take more than 90 business days but, depending on the complexity of the information requested by the ANLA and administrative delays, including whether it is necessary to establish a government committee to determine the viability of the project, the procedure may take between 165 and 265 business days, depending on whether the applicant is required to file additional information. The new procedure incorporates an oral hearing between the ANLA and the applicant in order to evaluate the information provided in the license application and whether it is necessary to request additional information about the proposed project. The ANLA will have no other opportunities to request additional information after this hearing.

 

The Ministry of Environment and Sustainable Development is also responsible for establishing guidelines regarding climate change policies for the hydrocarbon sector in Colombia. We are in compliance with those guidelines. At present, the Ministry of Environment and Sustainable Development has not proposed any specific steps for the implementation of the Kyoto Protocol as it relates to our operations. We are continuously monitoring climate change requirements that could be applicable to us.

 

A company that does not comply with the applicable environmental laws and regulations, does not execute the Environmental Management Plan (PMA) approved by the environmental authority or ignores the requirements imposed by an environmental license may be subject to an administrative proceeding initiated by the National Authority on Environmental Licensing or the regional environmental authorities established by Law 1333 of 2009. The proceeding may result in oral or written warnings, monetary penalties, fines, license revocation or the temporary or permanent suspension of the activity being undertaken. Apart from administrative sanctions, the Colombian judiciary or other law enforcement authorities may also impose civil and even criminal sanctions if environmental damages are verified as a consequence of having breached the environmental laws and regulations applicable to the project.

 

3.8.2.1.2.Royalties

 

In Colombia, the Nation is the owner of minerals and non-renewable resources located in the subsoil, including hydrocarbons. Thus, companies engaged in exploration and production of hydrocarbons, such as Ecopetrol, must pay to the National Hydrocarbons Agency (ANH), as representative of the National Government of Colombia, a royalty on the production volume of each production field, as determined by the ANH.

 

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Royalties may be paid in kind or in cash. Each production contract has its applicable royalty arrangement in accordance with applicable law. In 1999, a modification to the royalty regime established a sliding scale for royalty payments for crude oil and natural gas production fields discovered after July 29, 1999 and depending on the quality of the crude oil produced. Since 2002, as a result of the enactment of Law 756 of 2002, the royalty rate was fixed as a sliding scale depending on the produced volume from 8% for fields producing up to five thousand bpd to 25% for fields producing in excess of 600 thousand bpd. Changes in the royalty regime only apply to new discoveries and do not apply to fields already in the production stage as of July 29, 1999. Producing fields pay royalties in accordance with the royalty law in force at the time of the discovery.

 

Regarding natural gas, in accordance with Resolution 877 of 2013, as amended by Resolution 640 of 2014, starting on January 1, 2014, the ANH has received royalties in cash rather than in kind. Thus, the producer may dispose of its gas production volumes corresponding to royalties paid in cash.

 

3.8.3Regulation of Transportation Activities

 

Hydrocarbon transportation activity is considered a public interest activity in Colombia and a public service. As such, it is under governmental supervision and control, regulated mainly by the Ministry of Mines and Energy and the CREG.

 

Transportation and distribution of crude oil, liquefied petroleum gas and refined products must comply with the Petroleum Code, the Code of Commerce and all governmental decrees and resolutions. According to Law 681 of 2001, multipurpose pipelines owned by Ecopetrol (through Cenit) must be open to third-party use on the basis of equal access to all.

 

Notwithstanding the general rules for hydrocarbon transportation in Colombia, natural gas transportation is subject to regulations specific to the natural gas industry as issued by CREG, due to the categorization of natural gas distribution as a public interest activity under Colombian laws.

 

Transportation systems, classified as crude oil pipelines and refined product pipelines, may be owned by private parties. Pipeline construction, operation and maintenance must comply with environmental, social, technical and economic requirements under national guidelines and international standards for the oil and gas industry.

 

Construction of transportation systems requires licenses and local permits awarded by the Ministry of Mines and Energy, the Ministry of Environment and Sustainable Development and regional environmental authorities, respectively.

 

Crude oil transport

 

The regulatory framework relating to crude oil transportation accounts for both private use and public use pipelines. Private use pipelines are those built by the operating or refining entity for its own exclusive right and that of its affiliates. Public access pipelines are defined as pipelines built and operated by a public or private legal entity, for the purpose of publicly providing crude oil transportation services. The Colombian government, through the ANH, has a preferential right to use up to 20% of the total capacity of any public or private access pipeline to transport its share of production. However, for both private and public access pipelines, the ANH must pay the tariff for the pipeline use to transport its percentage of production.

 

The Ministry of Mines and Energy is responsible for reviewing and approving the design of and tracks for crude oil pipelines. The Ministry establishes transport rates based on information provided by the service providers. It also oversees the calculation and payment of hydrocarbon transport-related taxes and manages the information system for the oil product distribution chain.

 

In 2014, the Ministry updated the transport regulation and the rate calculation method for this line of business. It introduced a framework for the secondary market and incentives for new pipeline construction and current pipeline capacity expansions. According to the Petroleum Code, rates are to be revised every four years. During the scheduled revision of 2015 and due to the dramatic changes in international crude oil prices, the Ministry of Mines and Energy allowed, by means of Resolution 31 325 of 2015, transportation companies and oil production companies to engage in direct negotiations in order to agree on a tariff suitable for both parties. The negotiation period extends until June 2016, after which if no agreement is reached, tariffs are to be set by the Ministry of Mines and Energy in accordance with the criteria previously established by Resolution 72 146 of 2014.

 

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The Port Superintendence is the authority that oversees the port business for crude oil and refined products. Although this business is not regulated, market participants are required to report certain information to the Port Superintendence.

 

As a result of the enactment of Decree 119 of 2015, operators of private use hydrocarbon ports are currently able to provide hydrocarbon transport services to third parties pursuant to a mechanism established under that decree.

 

Refined products transport

 

In 2014 the CREG assumed responsibility for regulating product pipeline transportation from the Ministry of Mines and Energy, in addition to its pre-existing regulatory responsibility for liquefied petroleum gas, natural gas and electric energy transportation.

 

CREG is in the process of defining and introducing the transportation regulation and the rate calculation method for refined products. On September 25, 2015, CREG published the draft resolution that establishes the proposed regulations for transport of liquid fuels and liquefied petroleum gas. The primary goals and components of the proposed regulation are: a) to ensure access to the transport systems for liquid fuels and the LPG pipeline systems without discrimination; b) to promote the timely expansion of the transport system in line with the needs of the market; c) to promote competition and prevent restrictive practices; d) to separate the operations of refining and transport; and e) to ensure the efficient and continuous operation of transport systems. The CREG expects to finalize its transportation regulations in the third quarter of 2016.

 

3.8.4Regulation of Refining and Petrochemical Activities

 

Article 58 of the Petroleum Code establishes that oil refining activities can be developed throughout the Colombian territory and are not reserved to the State. However, Article 4 establishes that such activities are considered of public interest subject to governmental regulation, and the development of those activities must comply with technical requirements established by regulation.

 

In 2008, Law 1205 was issued with the main purpose of contributing to a cleaner environment. It established the minimum quality specifications for fuels in Colombia. Since August 2010, Ecopetrol has been selling diesel and gasoline at its refinery in Barrancabermeja in order to produce diesel and gasoline that complies with the requirements of the aforementioned law.

 

3.8.4.1Regulation of Liquefied Petroleum Gas (LPG) and Liquid Fuels

 

Wholesale marketing, transport, distribution and retail marketing of LPG are mainly regulated by CREG Resolution 74 of 1996, and subsequent resolutions. LPG in Colombia is primarily obtained through Ecopetrol’s refineries, field production and imports. The LPG must meet minimum quality standards to be marketed. Our wholesale marketing and transport activities are regulated by Resolution 53 of 2011 (as amended by Resolutions 108 of 2011, 154 of 2014 and 019 of 2015) and Resolution 092 of 2009 (as amended by Resolution 153 of 2014). The LPG price is regulated by CREG Resolutions 66 of 2007 and 59 of 2008.

 

According to Article 212 of the Petroleum Code and Law 39 of 1987 (added by Law 26 of 1989), the distribution of liquid fuels and their derivatives is considered a public utility. Consequently, individuals or entities engaged in these activities are subject to regulations issued by the Colombian government. The Government has the power to determine quality standards, measurement and control of liquid fuels, and establish penalties that may apply to dealers who do not operate in compliance therewith.

 

The Ministry of Mines and Energy is the entity that controls and exercises technical supervision over the distribution of liquid fuels derived from petroleum, including the refining, import, storage, transportation and distribution in the country. Law 812 of 2003 identified the agents of the supply chain of petroleum-based liquid fuels.

 

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The distribution of liquid fuels, except LPG, is governed by Decree 1073 of 2015, which establishes the requirements, obligations and penalties applicable to supply agents in the distribution, refining, import, storage, wholesale, transportation, retail sale and consumption of liquid fuels.

 

Decree 1073 of 2015 establishes the minimum technical requirements for the construction of storage plants and service stations. This Decree also regulates the distribution of liquid fuels, establishing the minimum requirements for distributors and the activities and types of agreements permitted for these agents. The Ministry of Mines and Energy also regulates the types of liquid fuels that can be sold and purchased and the penalties for noncompliance with governmental regulations.

 

The distribution of fuels in areas near Colombian borders is subject to specific regulations that impose strong control procedures and requirements. Ecopetrol is not responsible for fuel distribution in these areas. That responsibility was transferred to the Ministry of Mines and Energy, pursuant to Law 1430 of 2010.

 

The Ministry of Mines and Energy establishes the safety standards for LPG, storage equipment, maintenance and distribution of LPG. Resolution 31514 of 1992 established that any LPG household, commercial and industrial facility with a storage capacity of LPG greater than 420 pounds must receive an authorization from the Ministry of Mines and Energy prior to commencing operations.

 

The Domestic Public Service Superintendence also oversees the liquefied petroleum gas transportation business. Cenit reports key operational and financial indicators to it on a monthly basis.

 

3.8.4.2Regulation Concerning Production and Prices

 

According to the Decree - Law 4130 of 2011, it corresponds to the CREG set the prices of petroleum by-products throughout the entire chain of production and distribution except for current gasoline engine, diesel and biofuels. On the other hand, by Decree 381 of 2012, as amended by Decree 1617 of 2013, the Ministry of Mines and Energy is in charge of setting the methodology to determine the reference price of gasoline, diesel (ACPM), biofuels and mixtures thereof.

 

Then, since May 2012, CREG regulates the prices for most crude oil by-products, but for gasoline, diesel, ACPM and biofuels, CREG determines the methodology to calculate the price of those by-products, and the Ministry of Mines and Energy sets the relevant prices in accordance with the methodology established by CREG. The ANH does not intervene in the definition of prices of gasoline and diesel fuel.

 

The methodology for calculating jet fuel prices is set out in Law 1450 of 2011, and jet fuel prices themselves are set by the Ministry of Mines and Energy.

 

The ANH determines the formula that is used to calculate royalty payments corresponding to the production of crude oil and the crude oil price reference for local refining. 

 

Decree 381 of 2012 and 1617 of 2013, as amended by Decree 2881 of 2013, restructured the Ministry of Mines and Energy and gave it the responsibility to study industry problems and implement short- and long-term refining planning policies.  The Ministry is also responsible for establishing the governmental policies and goals to ensure the reliability, stability and continuity for the production of liquid fuels, biofuels and others.

 

Pursuant to Article 58 of the Petroleum Code, any refining company operating in Colombia must provide a portion or, if needed, the total of its production to supply local demand prior to exporting any production.  If local demand increases, and imported crudes are needed, the refining company may charge the State additional transportation costs in proportion to the imported crudes delivered to the refinery.

 

The Fuel Price Stabilization Fund (FEPC) was created by means of Law 1151 of 2007 with the aim to mitigate in the domestic market, the impact of fluctuations in fuel prices (gasoline and motor fuel oil) in international markets.  As per article 2.3.4.1.3 of Decree 1068 of 2015, the funding for the operation of the FEPC comes from the following sources:  (i) financial returns on the funds of the FEPC; (ii) extraordinary contributions from the National Treasury; and (iii) resources from the General Budget of Colombia.

 

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The FEPC is currently regulated by Decree 1068 which compiles Decree 1880 of 2014, which sets forth the calculation method of the Differential as the product of the volume reported by the refiner and/or importer to the Ministry of Mines and Energy times the difference between the international parity price and the reference price.  It also provides that refiners and/or importers shall submit monthly reports to the Ministry of Mines and Energy on the volume, origin and type of fuel (gasoline and motor fuel oil) sold in the domestic market for said period.  Based on those reports the Ministry of Mines and Energy shall calculate and liquidate the Net Position every six months by issuing a resolution provided, however, that such Net Position results from the sum of the Differentials for the relevant six-month period.  Decree 1068 of 2015 also provides that the FEPC shall pay in Colombian Pesos the value corresponding to the six-month Net Position of each refiner and/or importer within the term that the Ministry of Mines and Energy establishes and based on availability of resources of the FEPC.

 

Under Resolutions 31580 and 31581, the FEPC has paid to Ecopetrol COP$853.5 million and to Reficar COP$182.5 million relating to the last quarter of 2013 and the first and second quarter of 2014. The Ministry of Mines and Energy has not calculated the Net Positions for other quarters. According to the financial statements of Ecopetrol S.A., the estimated amount owned by the FEPC to Ecopetrol S.A. is COP$155.8 million based on the same methodology used by the Ministry to calculate the last payment, which possibly will be changed by the Ministry of Mines and Energy.

 

3.8.4.3Regulation of Biofuel and Related Activities

 

The sale and distribution of biofuels is regulated by the Ministry of Mines and Energy. Regulations establish the quality and pricing standards for biofuels and impose minimum requirements for mixing ethanol with gasoline and biodiesel with diesel.

 

3.8.5Regulation of the Natural Gas Market

 

Decree 1073 of 2015, issued by the Ministry of Mines and Energy, established that all producers have to issue a production statement that includes the volumes of natural gas available for sale for a period of ten years.  This decree established the regime for the selling and marketing of natural gas in Colombia, including specific procedures that regulate the Colombian market in order to manage the remaining natural gas reserves owned by the Nation, and to protect domestic consumers, especially residential consumers, by prioritizing delivery of gas to residential consumers, regulating the export of natural gas and setting forth the export restrictions applicable during an internal shortage of natural gas.

 

Currently in Colombia, other than with respect to the Opón field, the price of natural gas is determined by the market.

 

CREG issued Resolutions 088 of 2013 and 089 of 2013 that established the procedures for marketing natural gas in Colombia.  Pursuant to Decree 1073 of 2015, however, such procedures do not apply to the following activities:  a) natural gas exports; b) natural gas as raw material in petrochemical production; c) natural gas commercialization from minor fields (production capacity under 30 million cfpd); d) natural gas commercialization from hydrocarbon fields under testing phase or which have not yet been declared commercially viable; e) natural gas commercialization from unconventional reservoirs and f) internal consumption from natural gas producers.

 

CREG determines which agents can participate in the primary and secondary markets.  Ecopetrol is authorized to participate as a seller in the primary market as a natural gas producer and as a buyer in the secondary market when Ecopetrol requires natural gas from other producers for its own needs.  CREG regulations provide that a natural gas producer cannot participate as a merchant of natural gas in the secondary market except that it may purchase gas to meet its existing contractual obligations.  Ecopetrol is also able to re-sell available natural gas transportation capacity into the secondary market.

 

Priority for the Supply of Natural Gas

 

The export of natural gas, in contrast, is not considered a public utility activity under Colombian law and therefore is not subject to Law 142 of 1994.  Nevertheless, the internal supply of natural gas is a priority for the Colombian government and is considered to be a public utility complementary activity, and therefore public utility regulations apply to the internal supply of natural gas.

 

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Decree 1073 of 2015 (amended by Decree 2345 of 2015) provides that in the event the supply of natural gas is reduced or halted as a result of a shortage, the Colombian government has the right to suspend the supply of natural gas for exportation.  If such export contracts are suspended by the Colombian government, the export agents are entitled to receive compensation in accordance to article 2.2.2.2.15 and 2.2.2.2.38 of Decree 1073, 2015.  Notwithstanding the foregoing, Decree 1073 of 2015 establishes freedom to export natural gas under normal gas-reserve conditions.  Producers of natural gas may enter into natural gas export contracts if the ratio of proved reserves to consumption exceeds seven years, as determined by the Colombian Energy Planning Authority (or UPME for its Colombian acronym).

 

Decree 1073 of 2015 (amended by Decree 2345 of 2015) establishes an order of supply when restrictions are placed on the supply of natural gas or serious emergency situations arise that preclude the continued provision of certain services, as follows:  (i) essential demand, as established in Decree 1073 of 2015, (ii) non-essential demand under an existing agreement with a warranty of uninterrupted provision, and (iii) fair exports delivery.

 

The order of priority for the supply of natural gas is as follows:  (i) the operation of the compressor stations of the National Transportation System, (ii) residential users and small business users engaged in the distribution network, (iii) vehicular compressed natural gas and (iv) gas refineries, excluding those destined for self-generation of electricity that can be replaced with energy from National Transportation System, which has first priority.  The Ministry of Mines and Energy also establishes distribution priorities in the event of a natural gas shortfall derived from supply or infrastructure issues.  This order of priority is based on the type of contract, with firm supply contracts having priority over interruptible supply contracts.

 

Decree 1073 of 2015 and CREG Resolutions 089 of 2013 and 204 of 2013 provide specific procedures and forms of supply agreements determined by CREG pursuant to which an agent may sell and buy natural gas in the Colombian primary and secondary market produced from large fields (capacity of more than 30 million cfpd).  Decree 1073 of 2015 and CREG Resolution 089 of 2013 permits the sale of natural gas from small fields (capacity under 30 million cfpd) pursuant to contracts that fulfill certain regulatory requirements but whose form is not prescribed by law.

 

3.9Sustainability Initiatives

 

3.9.1HSE

 

This section describes the health, safety and environmental (HSE) practices of Ecopetrol S.A. Currently, subsidiaries of Ecopetrol S.A. establish their own HSE models, provided that these models must be consistent with guidelines established by Ecopetrol S.A.

 

3.9.1.1Ecopetrol S.A.

 

One of the principles that guide Ecopetrol is our commitment to our employees and the development of those communities in which we operate. For that reason, Ecopetrol S.A. is devoted to improving our health, safety and environmental (HSE) practices.

 

HSE management is essential for us; it promotes policies designed to recognize and understand process risks and prevent occupational accidents and other major incidents.

 

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We have several programs in place aimed at increasing the safety of our industrial processes and minimizing the number of occupational accidents and other major incidents. Our HSE management model is based on key focus areas that are aligned with our integrated management system. Based on these key focus areas, we have implemented the following aspects:

 

 

 

Strategy and management

 

·Align HSE policies with the Company Strategy, and generate programs to improve performance.

 

People

 

·Make HSE the highest priority for every employee and contractor.

 

·Promote participation and open communication with management.

 

·Establish a management control structure for HSE issues.

 

·Implement operational discipline designed to assure compliance in all operating and maintenance procedures.

 

·Institute safety corporate practices, including improving the competency of our employees and contractors with respect to critical processes of the company.

 

·Perform assessments of Process Safety Management (PSM) factors during the selection process of our contractors.

 

Information and knowledge-building

 

·Take inventory of information and technology related to PSM, especially as related to the processing of chemicals, and to design and develop a plan to update such information and technology for all facilities and to train our workers based on such updates.

 

Operations

 

·Ensure that our contractors perform critical maintenance procedures.

 

·Improve preparedness and emergency responses.

 

Resources

 

·Reduce risks through an inspection, testing and maintenance program designed to ensure the integrity of our critical equipment and parts.

 

Risks and controls

 

·Carry out our risk management strategies.

 

·Mitigate the impacts of occupational accidents and other major incidents by the implementation of controls.

 

·Intervene and remediate any technological risks identified in order to mitigate their effects.

 

·Improve the electrical skills of employees.

 

Monitoring and improving

 

·Promote self-assessments and perform regular mandatory assessments.

 

The results of these strategies in 2015, compared with the prior year, were:

 

·Zero fatalities associated with accidents.

 

·A 32% decrease in road accidents, due to improvements in real-time monitoring of drivers’ safety habits.

 

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·Improved performance during maintenance activities, in order to ensure proper safety practices.

 

·25,022 critical procedures training sessions for our workers.

 

·A reduction in the severity of occupational incidents.

 

·A reduction to zero of accidents during the start-up of projects or major maintenance.

 

·A reduction in oil spills.

 

·Improvement in reporting of minor oil spills and identification of their causes.

 

Contingency Plans and Environmental Remediation

 

All of our operational areas have preparedness and emergency response plans, each in accordance with Colombian legal requirements and our new internal guidelines for emergency management.

 

Our preparedness and emergency response plans have been developed based on our analysis of risk scenarios, the estimated consequences of these events and the implementation of strategies to be followed in response to each scenario.

 

The objectives of our contingency plans are to:

 

·Protect the health and safety of our workers, contractors and the communities in which we operate.

 

·Prevent oil spills and leaks of harmful substances in offshore and onshore areas, fires and explosions and mitigating environmental impacts.

 

Our contingency plans include:

 

·Procedures for the containment of oil and other harmful substances, as well as procedures to safeguard the safety of affected communities and the personnel involved in such containment actions.

 

·Strategies for responding to emergencies located outside of our facilities and mutual aid emergency plans, including actions developed with local environmental authorities, stakeholders, the local community and other organizations for containment and recovery of spilled product, and cleaning and recovery of affected areas, monitoring of the environmental effects and compensation for local communities and other affected persons.

 

Further, we are upgrading the skills of our fire brigade, ensuring the reliability of firefighting and emergency equipment and working on improving our performance during drills.

 

In offshore operations, our operator has the responsibility of designing and implementing plans and strategies aligned with international best practices that cover various emergency response scenarios.

 

Total Recordable Incident Rate – Employees and Contractors

 

Ecopetrol S.A. places an important emphasis on understanding, monitoring and controlling our impacts on workers and contractors.

 

Ecopetrol S.A. monitors a standard measure of occupational safety known as the Total Recordable Incidents Frequency Index (TRIF), which represents the number of employee or contractor injuries that require medical treatment or time off for every million hours worked.

 

TRIF has improved from 4.28 incidents per million hours worked in 2010, to 0.96 in 2015. In 2015, 62% of occupational accidents affecting our employees and contractors resulted in a medical treatment, restricted work or time away from work that lasted for three days or less. This represents a significant decline in the seriousness of injuries resulting from such occupational accidents. Additionally, in 2015, we had our best overall year in personal safety, as measured by recordable injuries and injuries requiring time away from work, and in process safety, as measured according API-754, which in turn results from the application of the HSE management system.

 

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Figure 1 – Total Recordable Incident Rate – Employees and
Contractors (*) (**)

 

 

 

 

*Number of employee or contractor injuries requiring medical treatment or time off for every million hours worked
**Includes data for Ecopetrol S.A. and the Vice-Presidency of Transport and Logistics, but does not include data for subsidiaries of Ecopetrol S.A.

 

Frequency of process safety incidents

 

Since 2009, we have been working on a “Process Safety Management” (PSM) system aimed at minimizing operational incidents, such as fire, explosion, loss of primary containment and multiple fatalities. Our PSM strategy is to: first, define high-risk processes; second, prioritize intervention in high-risk processes; and third, apply all PSM elements in the prioritized high-risk processes.

 

Loss of primary containment is the number of unplanned or uncontrolled releases of oil, gas or other hazardous materials.

 

We report tier 1 process safety events per million hours worked, which are the losses of primary containment of greatest consequence causing harm to a member of the workforce, costly damage to equipment or exceeding defined quantities according to API-754.  We reduced our tier 1 process safety indicator by 18% compared to 2014 (2015: 0.09 and 2014: 0.12).  Additionally, the consequence in costs associated with these incidents has declined by 70% in 2015 as compared to 2014. The reporting thresholds for API-754 Tier 1 is an unplanned or uncontrolled release of any material, including non-toxic and non-flammable materials, from a process that results in one or more health, safety or environmental consequences set forth under those guidelines. In 2015, there were 0.09 Tier 1 process safety incidents per million hours worked.

 

The consequences of these incidents decreased in 2015 compared to 2014.

 

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Frequency of Tier 1 process safety incidents per hours worked (per million hours worked):

 

Figure 2 – Tier 1 Process Safety Incidents (*) (**)

 

 

 

 

*Tier 1 process safety incidents per million hours worked (API-754)
**Includes data for Ecopetrol S.A. and the Vice-Presidency of Transport and Logistics classified according to the criteria in API-754 Tier 1, but does not include figures for Ecopetrol S.A.’s subsidiaries.

 

Environmental Incidents

 

In 2015, Ecopetrol S.A. recorded 11 environmental incidents compared with 29 in 2014 and 34 in 2013. The volume of oil spills was 207 barrels in 2015, a substantial decrease from 885 barrels in 2014 and 6,843 barrels in 2013. The decrease in the numbers of environmental incidents and oil spills was the result of the identification of critical equipment operating in high or very high risk conditions, and the implementation of asset integrity plans designed to mitigate those risk conditions.

 

3.9.1.2Cenit

 

While Cenit had previously followed Ecopetrol’s HSE guidelines, in 2015, Cenit established its own HSE practice and set and defined its own HSE Key Performance Indicators (KPIs) and targets in respect of its non-operative facilities and offices. This resulted in significant cost reductions with no change in risk levels. Local and field operations, however, are still conducted under Ecopetrol’s HSE model and guidelines.

 

3.9.1.3Refinería de Cartagena

 

In 2015, around 32.9 million man-hours were employed conducting Reficar’s business activities. Our HSE performance indicators for Total Accident Frequency Rate (AFR), Total Recordable Cases (TRIF), Total Accident Severity Rate (ASR) and Environmental Incident Index (EI) were well-within our established guidelines, as shown in the table below:

 

Table 41 – Performance Indicators

 

INDICATOR  OUTCOME 2015 
AFR*   0.95 
ASR**   0 
TRIF   1.73 
EI   0 

 

 

* Total Accident Frequency Rate (AFR) Construction (includes CB&I and construction subcontractors of CB&I)

** Total Accident Severity Rate (ASR) (includes CB&I and construction subcontractors of CB&I)

 

The results of other related performance indicators during 2015 were:

 

·Lost Time Injury Incidents: 26 incidents, which includes zero for Chicago Bridge & Iron Company (CB&I), 12 incidents for Ecopetrol and 14 incidents for Reficar and subcontractors.

 

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·Medical Treatment Injury: nine incidents without having an impact on working hours, which includes four incidents for Chicago Bridge & Iron Company (CB&I), zero incidents for Ecopetrol and five incidents for Reficar and subcontractors.

 

·Restricted Work Incidents: 22 incidents without having an impact on working hours, which includes one incident for Chicago Bridge & Iron Company (CB&I), four incidents for Ecopetrol and 17 incidents for Reficar and subcontractors.

 

·Environmental Incidents: zero incidents.

 

·First Aid Cases: 467 incidents.

 

In addition, in 2015 some of Reficar’s activities and results included:

 

·Performance of pre-start safety checks and receipt of “Ready For Start-Up” certificates for 100% of the units during the start-up process.

 

·Obtained accreditation of Reficar’s Vocational Center by the Colombian Ministry of Labor. 10,179 employees were trained to fulfill Resolution 1409 of 2012, which provides workplace safety standards for persons working at heights. Additionally, 23,412 employees were trained in several other labor certifications.

 

·Receipt of awards for excellence in HSE (Occupational Hazard Insurance of Reficar) from the workers’ compensation insurance company, ARL Sura.

 

·Implementation of emergency plans for all of Reficar’s units.

 

·Development of emergency drills before the commencement of operations of Reficar’s process units.

 

·Organized the HSE Occupational Health Week in Cartagena and Bogotá for Reficar, EPC contractors and other subcontractors.

 

·Development of campaigns to strengthen HSE culture and leadership in Reficar.

 

·Outstanding results of our Yearly Environmental Auditing Report, which revealed zero breaches of environmental regulations related to Reficar’s expansion project.

 

·Approval from the Colombian Geological Survey of the operation license of 63 radioactive sources for the Cartagena Refinery.

 

·Approval from the Colombian Geological Survey to import 63 radioactive sources for the Cartagena Refinery.

 

·9,401 maintenance trees planted under our Forestry Compensation Program regulated by environmental authorities.

 

·200 wildlife relocated under our wildlife program regulated by environmental authorities.

 

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Recent Performance

 

Over the last three years, our HSE performance has continuously improved. The following table and chart cover our Total Accident Frequency Rate (AFR) and Total Accident Severity Rate (ASR) from 2013 to 2015 for Construction and Total Recordable Incidents of Reficar, which includes Reficar’s EPC Contractors, CB&I and Reficar’s subcontractors. The first table presents statistics relating solely to the construction activities during the modernization and expansion project, whereas the second table provides general statistics for 2015, not only construction-related activities, but also pre-commissioning, start-up and operating activities. Reficar reported more than 110 million man-hours without a high severity accident (permanent injury or death).

 

Table 42 – Total Accident Frequency Rate

 

   For the year ended December 31, 
   2015   2014   2013 
Man-Hours   15,836,845    36,065,413    26,106,164 
Recordable Accidents   15    37    49 

 

   For the year ended December 31, 
   2015 
Man-Hours   32,944,698 
Recordable Accidents   57 

 

Figure 3 – Accident Frequency Rate (AFR)
Construction (*)
  Figure 4 – Total Accident Severity Rate
(ASR) Construction (*)
     

 

 

(*)Year-on-year figures are shown from December to December of each year.

 

3.9.2Human rights

 

Ecopetrol has a Human Rights Policy with an integrated and systemic management approach to human rights based on the due diligence principle, which we continued to strengthen in 2015.

 

Ecopetrol maintains corporate mechanisms to ensure its compliance with national and international human rights laws and certain non-binding international standards, as well as to generate value to the company and to society through the promotion of human rights. These mechanisms are:

 

·The Human Rights Committee;

 

·The Tactical Plan on Human Rights;

 

·The Human Rights Monitoring System; and

 

·Human rights and international humanitarian law risks analysis.

 

In view of our commitment to respect and promote human rights, Ecopetrol continues promoting these values in all of its controlled subsidiaries. In 2015 Ecopetrol developed a project to align the human rights standards among its subsidiaries, establishing an internal standard to manage human rights that takes into account the United Nations’ “Protect, Respect and Remedy Framework”, Global Compact Principles and Voluntary Principles on Security and Human Rights.

 

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Regarding human rights risks analyses, our monitoring process has been strengthened in order to prevent and mitigate negative impacts on human rights. As part of our monitoring process several human rights risks analyses have been conducted for particular projects in Ecopetrol. Additionally, Ecopetrol S.A. continues its work in promoting human rights in the several territories where it has operations, by promoting initiatives that support:

 

·Human rights dialogue with stakeholders,

 

·Rights of ethnic groups,

 

·Equal gender rights,

 

·Children and teenager rights,

 

·Right of association and collective bargaining and

 

·Business and peace.

 

Ecopetrol S.A. has carried out a human rights risk assessment in order to evaluate and mitigate human rights impacts. As a result of this assessment, Ecopetrol S.A. has focused its efforts on the following principles:

 

·Right to life, liberty and personal security,

 

·Right of association and collective bargaining,

 

·Abolition of forced or compulsory labor,

 

·Abolition of child labor,

 

·Equality and non-discrimination at work,

 

·Just, equitable, and satisfactory conditions of work,

 

·Rights of ethnic groups, and

 

·Collective rights and the environment.

 

3.9.3Dow Jones Sustainability Index

 

For the fifth consecutive year, Ecopetrol was listed in the Dow Jones Sustainability Index-World (DJSI). The DJSI is a global indicator that monitors the financial performance of leading companies committed to corporate sustainability. Ecopetrol remained within the top 10% (13 companies) of oil & gas companies around the world, among the 2,500 companies listed and included in the Dow Jones Index.

 

3.9.4Environmental Sustainability

 

3.9.4.1Environmental Practices

 

Ecopetrol S.A.

 

During 2015, the environmental management strategy of Ecopetrol included the following components:

 

1.Environmental Viability: this strategy concentrates on obtaining environmental licenses and permits as well as adequate land management that ensures the sustainability of operations through timely prevention efforts and management of environmental impacts, constant and systematic relationships with stakeholders and participation in the sustainable development of the territories in which we operate.

 

2.Climate Change: this strategy aims to decrease our carbon emissions and reduce the vulnerability of our operations and our facilities to the effects of climate change through the implementation of four strategic action lines:

 

·Mitigation: reducing our carbon dioxide emissions and creating carbon offset alternatives;

 

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·Vulnerability and Adaptation: reducing the risks and impacts to our operations posed by climate variability and change;

 

·Research and Technology: reducing our greenhouse gas emissions through action on research and development, process optimization, implementation of energy efficient strategies, carbon capture and sequestration and diversification into low carbon energy sources; and

 

·Involvement in Policymaking: informing and influencing government policies on climate change.

 

3.Biodiversity: this strategy aims to reduce Ecopetrol’s impacts on the ecosystems in areas where we operate. This strategy mainly focuses on knowledge building and conservation efforts in areas where we operate.

 

4.Eco-efficiency: this strategy aims to maximize our efficient use of resources and mitigate our environmental impacts. Through this strategy, which extends to our supply chain, we seek to utilize energy, materials, and in general all natural resources as efficiently as we can, thereby reducing the environmental impacts from our operations and projects and minimizing emissions, effluents and waste disposal from our operations and projects while taking into account our production benchmarks.

 

5.Integrated Management of Water Resources: this strategy aims to ensure compliance with water resources laws and reduce conflicts over water use in the areas near our projects and operations. Our core focus areas under this strategy are aligned with the objectives defined by the 2010 National Water Policy for the Management of Water Resources in Colombia which focuses on water supply, demand, quality, risk governance and institutional strengthening.

 

Since 2009, Ecopetrol has reported its achievements in the sphere of environmental management to various relevant organizations focused on promoting sustainable business practices, such as the Dow Jones Sustainability Index, the Carbon Disclosure Project (CDP) and the CDP Water Information Request; Environmental Benchmarking of ARPEL.

 

Refinería de Cartagena

 

Environmental Investments

 

In order to comply with EIA and Colombian regulations instituted in 2015, the following environmental investments were made:

 

Table 43 – Environmental Investments

 

Activity Description  Amount 
   (in millions of Colombian
Pesos)
 
Collection, Transport and Disposal of Medical and Hazardous Materials   91.4 
Collection of Ordinary Materials   2,227.1 
Wildlife Relocation and Vector Control   842.9 
Leasing and Maintenance of Portable Bathrooms   2,744.3 
Forestry Compensation Program (Waterbed of Refinery’s Stream)   297.9 
Forestry Compensation Program (Ciénaga de la Virgen)   38.6 
Project Monitoring Services (Air Quality and Noise Levels)   87.4 
Environmental Audits   59.7 
Total   6,389.3 

 

3.9.5Extractive Industries Transparency Initiative (EITI)

 

Colombia has officially adhered to the Extractive Industries Transparency Initiative (EITI) which promotes transparency on revenues and accountability in the extractive sector.

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Ecopetrol S.A. is participating in this initiative in two roles: (i) as a member of the National Tripartite Committee CTN, and (ii) as one of the 18 companies of the extractive industry chosen by the Colombian government for its importance and materiality that is working jointly with the Colombian government and other companies to contribute significantly to the transparency and public access to information of the sector.

 

Under the leadership of the Ministry of Mines and Energy and the participation of over 18 companies of the oil, gas and mining industry, including Ecopetrol S.A., the Colombian government prepared the first EITI report in Colombia using figures from fiscal year 2013. That report was published in February of 2016.

 

3.9.6Energy Projects

 

Refining

 

Ecopetrol’s refining companies have been undertaking significant efforts to make efficient and rational use of energy resources in its production processes and reduce energy consumption and costs and carbon dioxide emissions. We focus on efficiency, reliability and optimization, and energy diversification. During 2015, the refinery’s segment’s average monthly energy consumption was 61.726 MWhm (megawatts per hour per month) equivalents, from which 98.9% was provided through self-generation and the remaining 1.1% with non-regulated energy purchased from the National Transmission System.

 

The Barrancabermeja Refinery accomplished the following during 2015 in respect of energy projects:

 

·Construction of base lines of crude and the residual processing units to manage the reduction of energy consumption.

 

·Increased sales of excess electricity to other related parties.

 

·Commissioning and startup of a turbogenerator with additional production of vapor to increase energy efficiency.

 

·Reduction of gas consumption in boilers.

 

Reficar accomplished the following during 2015 in respect of energy projects:

 

·Monitoring of 13 new base lines to manage the reduction of energy consumption.

 

·Increased the refinery’s capacity to generate gas-turbine electricity;

 

·Added a sophisticated combined cycle design, to generate power in the most efficient way (state of the art).

 

·Installed software for monitoring and optimization of energy performance; and

 

·Optimization of the hydrogen network.

 

Production

 

Ecopetrol’s corporate strategy with respect to efficiency accomplished the following savings in the production sector during 2015:

 

·COP$2.7 billion from new and improved tariffs as a result of contract renegotiations with Ecopetrol´s contractors;

 

·COP$1.5 billion from the substitution of certain fuel sources; and

 

·COP$1.7 billion due to the startup of new generation centers.

 

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Further, during 2015, Ecopetrol S.A.’s production sector had an average a monthly energy consumption of 238.3 MW for its direct operation, from which 79% was provided through self-generation and the remaining 21% with non-regulated energy purchased from the National Transmission System.

 

Energy Surplus Sales

 

According to CREG and Public Services Superintendency regulations, a company that has power self-generation capacity, such as Ecopetrol, can sell its energy surplus to related companies, that is, companies from the same economic group.

 

In 2015, Ecopetrol, which has capacity in excess of its consumption of self-generated energy, sold surpluses of self-generated energy at the Barrancabermeja Refinery to Cenit and to Ecodiesel for COP$19.08 billion.

 

In the first quarter of 2016, the “El Niño” climate phenomenon caused Colombia’s dams to generate lower levels of energy, which had a great impact on the national electric system. To mitigate this situation, the Colombian government has allowed all companies with surplus energy, including Ecopetrol, to sell their surpluses of energy in the national electrical system.

 

3.10Related Party Transactions

 

Set forth below is a description of material related party transactions. For additional information about transactions with related parties, see Note 32 – Related Parties to our consolidated financial statements.

 

Ocensa

 

Ecopetrol S.A. has entered into a number of agreements with its 72.65%-owned subsidiary Ocensa, of which the following are the most significant:

 

·In March 1995, Ecopetrol S.A. entered into an agreement for the transportation of crude oil through the Ocensa pipeline. Pursuant to the terms of this agreement, Ecopetrol S.A. was required to make monthly payments that varied depending on both the volume of crude oil transported through the pipeline and a tariff imposed by Ocensa on the basis of Ocensa’s financial projections and their expected volumes of crude oil. On January 17, 2013, this agreement was amended as a result of Ocensa’s new business model. Among other changes, this amendment to the transportation agreement establishes the payment of the tariff calculated according to Resolutions issued in 2010 by the Ministry of Mines and Energy. In 2013, another amendment was executed that modified the terms by which the payments of invoices should be made. In 2015, payments made by Ecopetrol S.A. under this agreement amounted to US$925 million.

 

·In December 2011, Ecopetrol S.A. entered into an operation and maintenance agreement for the Porvenir, Miraflores and Vasconia pumping stations with Ocensa. In 2015, pursuant to the terms of this agreement, Ecopetrol S.A. received payments of approximately US$9 million at fixed and variable costs plus applicable taxes. Pursuant to the terms of the agreement, in September 2015 Ocensa notified Ecopetrol of its decision not to extend the term of the contract, which expired in March 2016.

 

·On July 10, 2012, Ecopetrol entered into a ship or pay agreement for the unloading of up to 8 thousand barrels per day of crude oil barrels at Ocensa’s unloading facilities. This agreement was later amended on March 12, 2013 and on July 19, 2013. The fees correspond to a cost of US$1.50 per barrel of crude oil that is unloaded. The agreement has a term of five years. On April 11, 2014 Ecopetrol entered into an additional ship or pay agreement for the operation of Ocensa’s unloading facilities by means of which Ecopetrol has the right to unload an additional volume of up to 2,000 barrels per day. The additional agreement has a five year term. On 2015, as a result of certain modifications made by Ocensa to the unloading facilities that make it possible to receive crude with lower API gravity, the parties signed an addendum to the agreement whereby crude of 18 API can be unloaded by Ecopetrol at Ocensa’s facilities. By virtue of these agreements, Ecopetrol S.A. paid fees of US$3.45 million to Ocensa in 2015.

 

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·On January 17, 2013, Ocensa and its shareholders – Cenit, Ecopetrol Pipelines International Limited, Santiago Pipelines Company, New Santiago Pipelines Company, Total Colombia Pipeline, Inversiones Sol del Sur S.A.S. and Cepsa Colombia S.A. – entered into a shareholders agreement that establishes the basis for a new business model, pursuant to which Ocensa has become a profit center instead of a cost center. This agreement became effective as of the date of execution and will be in effect until Ocensa is registered on an exchange. Additionally, this agreement might be renegotiated if the control structure of Ocensa is modified.

 

The Ocensa shareholders’ agreement establishes the basis for Ocensa’s corporate governance model. It provides for a board of directors composed of five members, two of which must be independent. Cenit may nominate three members of the board of directors, including the two independent members, while minority shareholders may together nominate the remaining two members.

 

The Ocensa shareholders’ agreement provides the minority shareholders with certain rights, including the right to nominate two members of the five-member board of directors. Significant decisions must be approved by a qualified majority of at least four Ocensa shareholders, and by supermajorities of the outstanding Ocensa shares. These actions include, among others (i) issuing additional shares or publicly listing shares, declarations of dividends in amounts other than all distributable income and certain amendments to Ocensa’s bylaws and (ii) asset sales in excess of US$50 million;

 

·On October 28, 2013, Ecopetrol entered into a natural gas supply contract in force until November 30, 2018, pursuant to which Ecopetrol S.A. supplies gas to Ocensa and receives a fixed price per MBTU (million British Thermal Units). This agreement replaced the contract for natural gas supply entered into on December of 2004, under which Ocensa paid a variable rate to Ecopetrol. In 2015, Ecopetrol S.A. received an aggregate sum of US$2 million under the contract.

 

Ocensa has entered into the following agreements, among others, with some of our other subsidiaries:

 

·In March 1995, Equion and Santiago Oil Company entered into agreements for the transportation of crude oil through the Oleoducto Central S.A. (Ocensa) pipeline. In November 2012, Equion and Santiago Oil Company transferred, by means of various transactions, its shares (24.8%) and transportation rights (19.8%) holdings in the Ocensa pipeline to wholly owned subsidiaries of Ecopetrol S.A. (51%) and Talisman (49%). Equion and Santiago Oil Company kept 5% of transportation rights in Ocensa. In 2014, the transportation fees billed by Ocensa were: Equion (US$44.4 million), Santiago Oil Company (US$3.8 million) and Hocol (US$30.8 million). On January 17, 2013, this agreement was amended as a result of Ocensa’s new business model. Among other changes, the amendment to the transportation agreement establishes that tariff payments are to be calculated according to resolutions issued by the Ministry of Mines and Energy. On May 23, 2013, another amendment was executed that modified the terms by which the payments of invoices should be made. In 2015, Ocensa billed Equion US$42.88 million and Santiago Oil Company US$3.69 million, in each case for transportation fees. Ocensa billed Hocol, as assignee of transportation rights from original shippers, US$15.58 million in 2015.

 

·On July 9, 2012, Ocensa and ODL entered into a strategic alliance for the dilution of crude oil in the Cusiana station. The term of this contract is of five years. One the initial term of the agreement ends, Ocensa has a purchase option over the assets that perform the dilution process. In 2015, the parties signed two addenda to the agreement in order to include additional construction work to be conducted by ODL and supervised by Ocensa for an agreed fee. ODL paid Ocensa US$4.03 million under this contract in 2015.

 

Oleoducto de Colombia S.A. (ODC)

 

Ecopetrol S.A. entered into the following agreements with its 73%-owned subsidiary ODC:

 

·In July 1992, a take-and-pay agreement was signed for the transportation of hydrocarbons. Pursuant to this agreement, Ecopetrol S.A. must pay a previously agreed tariff for the volume of hydrocarbons transported. The duration of this agreement is indefinite; however the contract will remain in force as long as Ecopetrol S.A. holds shares in Oleoducto de Colombia S.A., whether directly, or through an affiliate. As of January 2013, the parties agreed that the applicable tariff would be the one set by the Ministry of Mines and Energy (the “MME Tariff”). The MME Tariff had been set in 2011 for a four-year term, with a yearly adjustment based on the consumer price index. In 2015, payments made by Ecopetrol S.A. under this agreement amounted to US$103.78 million.

 

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·In August 1992, an operation and maintenance agreement was signed for the Vasconia and Coveñas terminals both property of ODC. The duration of this agreement is indefinite, but can be terminated by any party upon six-months’ notice. The initial contract included services rendered by Ecopetrol directly or by third-party contractors hired by Ecopetrol through mandate; with a variable surcharge over expenses and third-party contracts between 5% and 12% plus any applicable taxes. In 2014, an amendment to the agreement was signed, adjusting the monthly fixed rate to include expenses of services rendered directly by Ecopetrol, plus an additional 10% fee, and to eliminate the administrative surcharge. The contract also includes a variable sum related to contracts and purchases made by Ecopetrol through mandate. In March 2015, the monthly rate was adjusted for both Vasconia and Coveñas Stations. Pursuant to the terms of this agreement, ODC paid approximately US$22 million in 2015.

 

·In March 1998, a joint operation agreement was signed for the TLU-1 Coveñas buoy. The duration of this agreement is indefinite and can be terminated by mutual agreement. In December 2013, Ecopetrol S.A. assigned its rights under this agreement to Cenit, though Ecopetrol S.A. kept its role as operator under the agreement. Pursuant to the terms of this agreement, ODC paid Ecopetrol S.A. approximately US$10 million in 2015.

 

·In September 1999, a joint operation agreement was signed for the TLU-3 Coveñas buoy between Ocensa, ODC and Ecopetrol. Pursuant to the terms of this agreement, ODC paid approximately US$6 million in 2015. The duration of this agreement is indefinite. In December 2013, Ecopetrol S.A. assigned its rights under this agreement to Cenit, though Ecopetrol S.A. kept its role as operator under the agreement.

 

·In July 2006, an operation and maintenance agreement was signed for the Caucasia station and the Vasconia-Coveñas pipeline system. The duration of this agreement is indefinite. Since 2010, this agreement only covers the operation of the Caucasia station and the Vasconia-Coveñas pipeline system, both property of ODC. The initial contract included services rendered by Ecopetrol directly or by third party contractors hired by Ecopetrol through mandate; with a variable surcharge over expenses and third party contracts between 5% and 12% plus any applicable taxes. In 2014, an amendment to the agreement was signed, adjusting the monthly fixed rate to include expenses of services rendered directly by Ecopetrol, plus an additional 10% fee, and to eliminate the administrative surcharge. The contract also includes a variable sum related to contracts and purchases hired by Ecopetrol through mandate. In 2015 an addendum was signed which adjusted the fixed rate. In 2015, ODC paid Ecopetrol US$9 million under this agreement.

 

ODC has entered into the following agreements with some of our other subsidiaries:

 

·Between March 1992 and January 1993, Hocol, Equion and Santiago Oil Company each entered into agreements with ODC for the transportation of crude oil through the Vasconia-Coveñas pipeline. The term of each of these agreements is indefinite. As of January 2013, the applicable tariff is the one set by the Ministry of Mines and Energy. In 2015, the transportation fees billed by ODC were: Equion (US$21.63 million), Santiago Oil Company (US$0.56 million) and Hocol (US$46.92 million).

 

Oleoducto de los Llanos Orientales (ODL)

 

Ecopetrol S.A. has entered into the following agreements, among others, with its 65%-owned subsidiary ODL:

 

·In March 2009, Ecopetrol S.A. entered into a ship-or-pay agreement with ODL that establishes a financing tariff used to pay ODL’s indebtedness to Grupo Aval for five years. This agreement was superseded by a new contract executed in May 2010, with a seven-year term, to reflect new conditions agreed with Grupo Aval. In August 2013, this contract was amended, providing a new term of seven years, including two two-year grace periods, and an interest rate of DTF + 2.5%. This financing tariff is collected through a trust fund, which in turn is responsible for making the debt service payments to Grupo Aval. Under this agreement, ODL has committed to transport 75,000 bpd during the initial two-year grace period of the facility and 90,000 bpd during the remaining years including the new term. Ecopetrol S.A. is responsible for 65% of this capacity. Payments by Ecopetrol S.A. under this contract were COP$50 billion in 2015.

 

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·In September 2009, Ecopetrol S.A. entered into a second ship-or-pay agreement with ODL that establishes a financing tariff collected through a trust fund that in turn is responsible for making debt service payments to security holders. Under this agreement, ODL committed to transport 19,500 bpd during the first phase of the ODL project (which began in September 2009 and ended in the first quarter of 2010) and 39,000 bpd upon commencement of the second phase of the ODL project which occurred in the first quarter of 2010 and finishes in the third quarter of 2016. Payments by Ecopetrol S.A. under this contract were COP$116 billion in 2015.

 

·In December 2009, Ecopetrol S.A. entered into a service agreement with ODL to transport crude oil. This agreement was replaced in January 2014 by a new agreement that expires in December 2020. This is a “ship or pay” agreement covering 167,000 bpd for 2014, 149,000 bpd for 2015 and 139,000 bpd until 2020. Payments by Ecopetrol S.A. under this contract were COP$409 billion in 2015.

 

·In March 2010, Ecopetrol S.A. entered into a pipeline operating and maintenance agreement with ODL. This agreement had an original five-year term and was amended in 2015 to extend the term another five years, adjusting certain conditions. Pursuant to the terms of this agreement, ODL paid to Ecopetrol S.A. COP$9 billion in 2015.

 

·In July 2013, Ecopetrol S.A. entered into a service agreement with ODL to dilute, in the facilities of the Cusiana field, crude oil transported in the Rubiales – Monterrey/Cusiana pipeline, with a committed capacity of 182,000 bpd. For 2015, 111 thousand bpd of the committed capacity corresponds to the “take or pay” volume. Payments by Ecopetrol S.A. under this contract were COP$23.8 billion in 2014. In 2014, this contract was amended to include an oil transfer service that has a “take or pay” volume of 15,000 bpd. Payments by Ecopetrol S.A. under this contract were COP$28 billion in 2015.

 

Oleoducto Bicentenario de Colombia S.A.S.

 

Ecopetrol S.A. has entered into the following agreements, among others, with its 55.97% owned subsidiary Oleoducto Bicentenario:

 

·In November 2011, Ecopetrol S.A. signed a five-year technical assistance services contract for the construction of the Araguaney-Coveñas pipeline. This contract finished its first phase on June 30, 2014. Future phases are under evaluation.

 

·In June 2012, Ecopetrol S.A. entered into ship-or-pay and ship-and-pay crude oil transportation agreements with Oleoducto Bicentenario that establish a price, which requires the payment of Oleoducto Bicentenario’s indebtedness to local banks for 12 years. This tariff is collected through a trust; the trust is also responsible for making the debt service payments to the banks. The duration of the ship-or-pay agreement is the earlier of 12 years or when the credit has been entirely paid, and the duration of the ship-and-pay agreement is 20 years after the ship-or-pay terminates. Under these agreements, Oleoducto Bicentenario has committed to transport at least 110,000 bpd, of which the 55% of the agreement volume is provided directly by Ecopetrol S.A. and 0.97% indirectly by Hocol. Pursuant to the terms of this agreement, in 2015 Ecopetrol paid to Bicentenario S.A. COP$548 billion plus applicable taxes. In March 2014, the parties signed an amendment to this contract under which Oleoducto Bicentenario acknowledges having received an advance tariff payment which can be amortized through volumes of crude transported in excess of 110,000 bpd. In April 2015, this contract was amended to modify certain definitions to reflect new terms from the negotiation of the debt, which included a modification of participant banks and a reduction of the interest rate.

 

·In June 2012, Ecopetrol S.A. entered into storage or pay and storage and pay agreements with Oleoducto Bicentenario. Under these agreements, Oleoducto Bicentenario is committed to receive, store, preserve and deliver our crude oil. The storage or pay agreement will terminate when Oleoducto Bicentenario’s indebtedness to local banks has been entirely paid, and the duration of the storage and pay agreement is 20 years after the storage or pay agreement terminates. In April 2015, this contract was amended to modify certain definitions to reflect new terms from the negotiation of the debt, which included a modification of participant banks and a reduction of the interest rate. Pursuant to the terms of this agreement, in 2015 Ecopetrol paid to Bicentenario COP$26.5 billion plus applicable taxes.

 

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·In August 2012, Ecopetrol S.A. entered into an Operation and Maintenance agreement for the Araguaney – Banadia pipeline system. The duration of this agreement is 15 years. Pursuant to the terms of this agreement, Ecopetrol S.A. received COP$9 billion plus reimbursable expenses in 2015.

 

Ecodiesel

 

·Ecopetrol S.A. entered into a supply agreement with Ecodiesel Colombia S.A. (“Ecodiesel”), a company in which Ecopetrol S.A. has a 50% equity interest. This agreement has been operative since August 1, 2010. Pursuant to the terms of this agreement, Ecodiesel must deliver to Ecopetrol S.A. and Ecopetrol S.A. must in turn purchase 48,100 barrels of Ecodiesel’s biodiesel production each month. Payments vary depending on the purchased volumes and the prices of biodiesel. This agreement expires on December 31, 2017. In 2015, a total of COP$273 billion was paid under this contract.

 

Savia Peru S.A.

 

·On February 19, 2016, Ecopetrol S.A., as lender and shareholder of 50%, and Savia Perú, as borrower, entered into a five-year loan agreement for an aggregate principal amount not to exceed US$70 million. The proceeds of the facility will be used to i) repay short term loans, ii) payment of shortfalls related to final judgments (in case they materialize). The loan agreement accrues interest at an annual rate of 4.99%, which can be adjusted on an annual basis, with semi-annual interest payments and principal payments beginning on the 21st month following the disbursement date. As of April 2016, Ecopetrol disbursed US$13.5 million under the loan agreement. Korea National Oil Corporation (KNOC), as shareholder of the other 50% of Savia Perú, signed a facility under the same terms and conditions as described above.

 

Transactions with Other State-Controlled Entities

 

Other than the agreements that we have entered into with the ANH and described in the section Business Overview—Exploration and Production—Joint Venture and Other Contractual Arrangements, in the ordinary course of business we enter into transactions with other state-owned entities that include but are not limited to the following:

 

·Selling and purchasing goods, including crude oil purchases of ANH royalties (see below);

 

·Properties and other assets;

 

·Rendering and receiving services;

 

·Leasing assets;

 

·Depositing and borrowing money; and

 

·Using public utilities.

 

For the years ended December 31, 2015 and 2014, we purchased the following volumes of crude oil from the ANH (National Hydrocarbon Agency) corresponding to royalties paid in kind by oil producers in Colombia: 45.6 million barrels and 45.4 million barrels, respectively. See the section Business Overview—Applicable Laws and Regulations—Regulation of Exploration and Production Activities—Business Regulation—Royalties for a description of the current royalty scheme.

 

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3.11Insurance

 

We have a clear and defined corporate policy based on risk financing guidelines that summarizes the Company’s risk transference and retention alternatives and provides support and guidance for all the insurance-related issues of all of our affiliated and subsidiary companies.

 

There are two corporate insurance programs covering Ecopetrol S.A. and its subsidiaries. In the text and tables below, we set forth our insurance programs and the companies covered, along with limits and coverage details.

 

World-Wide Umbrella Program: This insurance program provides coverage for downstream (assets and operations) of Ecopetrol S.A. and all of its subsidiaries in excess of their local insurance programs, and also in excess of the “Global Energy Package” program, when applicable. Coverage includes all physical damage, sabotage and terrorism, general liability, directors and officers, crime and marine cargo. Physical damage, sabotage and terrorism coverages were designed to cover downstream operations, while general liability, directors and officers, crime and marine cargo coverages were designed to cover down-, mid- and upstream operations.

 

Table 44 – World-Wide Umbrella Program

 

  

Limit (eel/agg(1))

  Deductible                              
Policies  Onshore  Offshore  Onshore  Offshore  Ecopetrol
Downstream
  Reficar  Propilco  Ecopetrol
Upstream
  Equion  Hocol  Ecopetrol
America
 

Ecopetrol
Brazil(2)

  ODL  Cenit
   (US$ in million)                              
Property – all risk  2,000  NA  5  N/A  X  X  X  NA  NA  NA  NA  NA  NA  NA
Sabotage and terrorism  600  NA  0.5  N/A  X  X  X  NA  NA  NA  NA  NA  NA  NA
Third-party Liability  500  NA  1  NA  X  X  X  X  X  X  NA  NA  X  X
Crime  75/150  NA  Various  NA  X  X  X  X  X  X  NA  NA  NA  X
Directors and Officers  250  NA  Various  NA  X  X  X  X  X  X  X  X  NA  X
Cargo  250  NA  3% Dispatch  NA  X  X  NA  X  NA  X  NA  NA  NA  NA

 

 

(1)Eel: each and every loss. Agg: Aggregate.
(2)There are no insurable assets in Brazil.

 

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Global Energy Package. This program provides coverage for upstream and midstream (assets and operations) of Ecopetrol’s interests and all of its upstream subsidiaries, including all physical damage, sabotage and terrorism, general liability and control of wells.

 

Table 45 – Global Energy Package

 

  

Limit (eel/agg(1))

  Deductible                     
Policies  Onshore  Offshore  Onshore  Offshore  Ecopetrol
Upstream
  Equion  Hocol  Ecopetrol
America
  Ecopetrol
Brazil
  ODL  Cenit
   (US$ in million)                     
Property – all risk  400  400  0.25  0.25  X  X  X  X  NA  X  X
Sabotage and terrorism  55  55  0.5  N/A  X  X  X  NA  NA  X  X
Third-party Liability  NA  500  N/A  0.15  X  NA  NA  X  X  NA  NA
Control of wells  250/50(2)  400  0.25-0.5  5  X  X  X  X  X  NA  NA

 

 

(1)Eel: each and every loss. Agg: Aggregate.
(2)Drilling US$250M / Production US$50M

 

Our third-party liability insurance policies cover Ecopetrol S.A., our subsidiaries and affiliates in excess of local underlying policy limits for claims made against them by third parties. Our commercial general liability, umbrella liability, and excess liability coverage will pay on behalf of or indemnify amounts for which an insured becomes legally obligated to pay, including damages in respect of bodily injury, property, pollution and product liability. Coverage of bodily injury and property damage is subject to coverage territory during the policy period.

 

With respect to offshore operations in the U.S. Gulf Coast, Ecopetrol America Inc. is party to Operating Agreements, or OAS, that include customary conditions and which contain similar terms and provisions to those in the Model Form of Offshore Deepwater Operating Agreement of the American Association of Professional Landmen. In general, pursuant to these OAs, the obligations, duties, and liabilities of the contract parties are several, and not joint or collective, for all operations covered by the OAs.

 

Ecopetrol Óleo e Gás do Brasil Ltda. and Ecopetrol del Perú are parties to Joint Operating Agreements (JOA) based on the Association of International Petroleum Negotiators model. Liability is generally the same as described for the OAS above, with the following variations: if claims arise from third parties as part of a claim not involving an operator’s gross negligence or willful misconduct, and the operator pays such claims, all parties must concur and reimburse such claim amounts. In certain contracts, all environmental damages are distributed according to the parties’ participation interest, regardless of whether the damages were caused by an operator’s gross negligence or willful misconduct. In certain cases, non-operators may intervene and directly verify compliance of the operator’s HSE programs.  Ecopetrol uses the same liability clauses in JOAs for offshore operations in Colombia, when Colombian laws do not govern such agreements.

 

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3.12Human Resources/Labor Relations

 

3.12.1Employees

 

As of December 31, 2015, Ecopetrol S.A. had 8,731 employees, a decrease of 4.8% from 2014. Most of our employees are located in Colombia. The table below presents the breakdown of Ecopetrol employees according to the business segments where they work, and the personnel of our subsidiaries for the years ended December 31, 2015, 2014 and 2013.

 

Table 46 – Corporate Group’s Employees

 

   As of December 31, 
  

2015(3)

  

2014(2)

  

2013(1)

 
   (number of employees) 
Ecopetrol S.A.               
Exploration and Production               
Exploration   218    187    188 
Production   1,880    2,022    1,867 
Others   457    429    437 
Total Exploration and Production   2,555    2,638    2,492 
Downstream               
Refining   2,700    2,771    2,716 
Marketing   136    199    187 
Others   6    19    18 
Total Downstream   2,842    2,989    2,921 
Transport   1,158    1,251    1,184 
Others   61    3    0 
Total Operations   6,616    6,881    6,597 
Corporate   2,115    2,269    2,203 
TOTAL ECOPETROL S.A.   8,731    9,150    8,800 
Ecopetrol America Inc.   75    57    47 
Bioenergy S.A.   122    96    106 
Bioenergy Zona Franca S.A.S.   126    94    92 
Hocol S.A.   172    185    197 
Equion Energía Limited   458    462    486 
Oleoducto Central S.A.   271    249    245 
Oleoducto de Colombia S.A.   2    1    1 
Oleoducto de los Llanos S.A.   56    33    16 
Oleoducto Bicentenario de Colombia S.A.S.   0    39    28 
Ecopetrol del Perú S.A.   0    0    2 
Refinería de Cartagena S.A.   270    247    234 
Ecopetrol Óleo e Gás do Brasil Ltda.   17    14    14 
Polipropileno del Caribe S.A. (Esenttia S.A.)   388    374    353 
Cenit Transporte y Logistica de Hidrocarburos S.A.S.   76    75    65 
TOTAL   10,765    11,076    10,686 

 

 

(1)193 persons employed by us during 2013 were not included in our 2013 employee statistics as they were independent contractors involved in non-regular activities and cannot be classified as temporary employees.
(2)79 persons employed by us during 2014 were not included in our 2014 employee statistics as they were independent contractors involved in non-regular activities and cannot be classified as temporary employees.
(3)31 persons employed by us during 2015 were not included in our 2015 employee statistics as they were independent contractors involved in non-regular activities and cannot be classified as temporary employees.

 

Loans and investment on training and development for our employees

 

To improve the quality of life of our employees, Ecopetrol S.A. extends various types of loans to its employees, including housing loans and general-purpose loans. The principal amount of the loan depends on the applicant’s tenure and cannot exceed 59 times the applicant’s monthly salary. Ecopetrol S.A. does not guarantee any loans made by third parties. In 2015, Ecopetrol S.A. extended 1,099 housing loans for a total of COP$ 170 billion and 1,633 general-purpose loans for a total of COP$12 billion. Ecopetrol S.A. also provided on-site and external training and development, which total to COP$10.02 billion, and it extended a total of COP$99 billion in subsidies for education.

 

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We have not provided loans (including housing loans), extended or maintained credit lines, arranged for the extension of credit by third parties, materially modified or renewed an extension of credit lines, in the form of a personal loan to or for any of our executive officers since our ADSs were registered under the Exchange Act.

 

Due to the replacement of several Senior Managers that took place in 2015, there are no more executive officers with housing loans in Ecopetrol.

 

Labor Regulation

 

In accordance with article 123 of the Colombian Constitution and the article 7th of the Law 1118 of 2006, our employees are considered “public servants”; even though they are subject to the common labor law. As such, their behavior is subject to the rules to those who handle public interests and goods and could be held liable for their illegal actions and omissions pursuant to the following regimes (1) disciplinary (Law 734 of 2002), (2) criminal or (3) civil.

 

3.12.2Collective Bargaining Arrangements

 

Ecopetrol S.A.

 

A collective bargaining agreement between us and our main labor unions governs labor relations with our unionized employees, which amounted to 3,815 employees as of March 4, 2016. The agreement also governs our labor relations with the 803 non-unionized employees that agreed to abide by it after requesting a waiver of Agreement 01 of 1977 or that belong to the technical operations career structure.

 

We currently have three industry-wide labor unions and six company labor unions:

 

·Unión Sindical Obrera de la Industria del Petróleo — USO (industry labor union);

 

·Asociación de Directivos Profesionales, Técnicos y Trabajadores de las Empresas de la Rama de Actividad Económica del Recurso Natural del Petróleo y sus Derivados de Colombia — ADECO (industry labor union);

 

·Sindicato Nacional de Trabajadores de Empresas Operadoras, Contratistas, Subcontratistas de Servicios y Actividades de la Industria del Petróleo y Similares — SINDISPETROL (industry labor union); and

 

·Asociación de Profesionales de Ecopetrol — ASPEC (company labor union).

 

·Sindicato Nacional de Trabajadores de Ecopetrol — SINCOPETROL (company labor union).

 

Notified to Ecopetrol in 2016:

 

·Asociación Sindical de Empleados de Ecopetrol – ASOPETROL (company labor union)

 

·Asociación Sindical de Trabajadores de Ecopetrol – TRASINE (company labor union)

 

·Asociación Sindical de Trabajadores de Ecopetrol – ASTECO (company labor union)

 

·Sindicato de Trabajadores Petroleros de Ecopetrol – SINPECO (company labor union)

 

Currently Ecopetrol S.A. does not have any workers in the SINCOPETROL union. This union does not participate in the negotiation process.

 

Any employee working for any company in the oil and gas industry may join the USO, ADECO or SINDISPETROL. Only our employees may join the company labor Unions.

 

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Ecopetrol S.A. relations with unions are based on a permanent dialogue and communication sessions where different matters are discussed in order to solve and prevent any labor conflict.

 

The following are the relevant terms of the five-year collective bargaining agreement in effect since 2014 and expiring on June 30, 2018. In 2016 the agreement could be reviewed on application matters, except for monetary expenses (including wages and benefits) and the scope of the agreement cannot be changed.

 

This agreement currently covers all workers benefiting from the Collective Labor Convention, regardless of whether they are part of any labor union:

 

·Education Subsidy. This subsidy covers 90% of tuition and board expenses and fixed amounts of transportation and textbooks for our employees and their children.

 

·Health Care Benefits. We pay 100% of medical expenses for workers and their families. According to internal regulations, families includes spouses, permanent companions, children under 18, children between 18 and 25 if they are studying, and economically dependent parents. The health benefits include comprehensive health care service, and programs in the prevention of diseases, the supply of medicines and others.

 

·Six-Months’ Bonus. Ecopetrol S.A. pays an additional 48 days of regular wage to all its workers each year: 24 days of additional regular wage in June and 24 in December.

 

·Stability Clause. Employees affiliated with the Unión Sindical Obrera de la Industria del Petróleo – USO (labor union) or Asociación de Directivos Profesionales, Técnicos y Trabajadores de las Empresas de la Rama de Actividad Económica del Recurso Natural del Petróleo y sus Derivados de Colombia – ADECO (industry labor union) who, as of December 1, 2004, had worked over 16 months continuously, cannot be terminated without good cause. 1,488 employees, approximately 17% of employees, are covered by this clause and additionally 679 could potentially also be benefited.

 

·Pension Plan for Employees. 26 employees that were hired before January 29, 2003 and fulfilled the company pension plan requirements before July 31, 2010 are covered by a company run pension plan. The other 8,705 employees are covered by the national social security system (99.7% of employees).

 

·Five-Year Bonus. A cash bonus accrues on a yearly basis and is paid out at the end of each five-year period that an employee works for Ecopetrol S.A. These bonuses increase incrementally over the length of an employee’s employment with the Ecopetrol S.A., and range from a payment equivalent to five days’ minimum wage for an employee who has worked for the Ecopetrol S.A. for a total of five years to 45 days’ minimum wage for an employee who has worked for the Ecopetrol S.A. for 45 years.

 

4.Financial Review

 

Our consolidated financial statements for the years ended December 31, 2014 and 2015 were prepared in accordance with IFRS. Our date of transition to IFRS was January 1, 2014. These consolidated financial statements are our first financial statements prepared in accordance with IFRS.

 

Until December 31, 2014, we prepared our audited consolidated financial statements in accordance with Colombian Government Entity GAAP issued by the Contaduria General de la Nación with reconciliations to U.S. GAAP. As required by IFRS 1—First Time Adoption of International Financial Reporting Standards— our financial position and results of operations for the year ended December 31, 2014 have been restated in accordance with IFRS. Note 35 to our consolidated financial statements contains an analysis of the presentation and disclosure effects of adopting IFRS and the effects on equity and net income for the fiscal year ended December 31, 2014 as of January 1 and December 31, 2014. The selected financial information for 2014 included in this annual report differs from the information we previously published for 2014, because it is presented in accordance with IFRS for comparative purposes, as required by IFRS 1. Following our adoption of IFRS, we are no longer required to reconcile our financial statements to U.S. GAAP.

 

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In addition, IFRS differs in certain significant respects from the current Colombian IFRS (which is the accounting standard we use for local reporting purposes). As a result, our financial information presented under IFRS is not directly comparable to any of our financial information presented under Colombian IFRS. A description of the differences between Colombian IFRS and IFRS is presented underSummary of Differences between Internal Reporting (Colombian IFRS and IFRS) below.

 

Our consolidated financial statements were consolidated line by line and all transactions and significant balances between affiliates have been eliminated. These financial statements include the financial results of all subsidiary companies controlled, directly or indirectly, by Ecopetrol S.A. See Exhibit 1 – Consolidated companies, associates and joint ventures, to our consolidated financial statements included in this annual report.

 

4.1Factors Affecting Our Operating Results

 

Our operating results were affected mainly by international prices of crude oil and, to a somewhat lesser extent, international prices for refined products and local prices for natural gas, as well as sales volumes, product mix, and our operational performance. Crude oil prices and volumes are particularly important to the results of our exploration and production segment. This is because as export volumes or export prices of crude oil decrease or increase, so do revenues. Results from our refining activities are also affected by conversion ratios, utilization rates and refining capacity, all of which affect our refining margins. Changes in the value of foreign currencies, particularly the U.S. dollar against the Colombian Peso, can also have a significant effect on our financial statements. Finally, terrorist attacks by guerillas against our pipelines and other facilities can lead to loss of revenues by restricting the availability of transport systems for exports or sales of crude oil and products in addition to the direct costs of repair and cleaning.

 

Sales volumes and prices

 

Our results from the exploration and production segment depend on our sales volumes and average local and international prices for crude oil and natural gas. Additionally, sales volumes are affected by the purchase of crude oil and natural gas that we make from third parties and the ANH.

 

We sell crude oil mainly in the international market as exports. We also process crude oil at the Barrancabermeja and Reficar refineries and sell refined and other petrochemical products in local and international markets.

 

Local sales and prices

 

We have a number of crude oil short-term commercial agreements with local customers, including producers of IFOS (Intermediate Fuel Oil) for the bunker industry in Colombia, and natural gas long-term supply contracts with gas-fired power plants and local natural gas distribution companies. Local sale prices are determined in accordance with existing regulations, contractual arrangements and the spot market linked to international benchmarks or export prices. Local sales have accounted for 46% of our total revenues, on average, for the past two years.

 

International Sales and Prices

 

Our foreign sales have accounted for 54% of our total revenues, on average, for the past two years.

 

International sale prices are determined in accordance with contractual arrangements and the spot market linked to international benchmarks primarily ICE Brent and Maya benchmarks.

 

Our commercial strategy focuses on market diversification. We sell our products in various regions, such as Asia, the U.S. Gulf Coast, U.S. Atlantic Coast, Europe, Central America and the Caribbean. In our negotiations with potential customers, we seek to use the most liquid benchmark reference prices in each region.

 

Exploration costs

 

We account for exploratory drilling costs using the successful efforts method, whereby all costs associated with the exploration and drilling of productive wells are initially capitalized. Costs incurred in exploring and drilling of dry or unsuccessful wells are expensed in the period in which the well is determined to be a dry or unsuccessful well and are accounted for under “Exploration and Project expenses.” Consequently, an increase in the number of exploratory wells we declare as dry or unsuccessful will negatively affect our results and may cause volatility in our operating expenses.

 

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Royalties

 

Each of our production contracts has its own royalty arrangement in accordance with applicable law. Historically, Law 141 of 1994 established a royalty fixed rate equivalent to 20% of total production. In 1999, a modification to the royalty system established a sliding scale for royalty percentage linked to the production level of crude oil and natural gas to fields discovered after July 29, 1999, depending on whether the production is crude oil or natural gas, and on the quality of the crude oil produced. Since 2002, the royalty percentage has ranged from 8% for fields producing up to five thousand bpd to 25% for fields producing an excess of 600 thousand bpd. Producing fields pay royalties in accordance with the applicable royalty rate at the time of the discovery.

 

Since January 2014, the ANH has collected natural gas production royalties from producers settled in cash based on a formula, regardless of whether a producer has sold the gas. As a result, we no longer commercialize this gas on behalf of the ANH. In addition, because the royalties are now payable to the ANH in cash, all of the gas we produce is counted as part of our production, without any deduction for royalties. The cost of natural gas royalties totaled COP$481,029 million in 2015.

 

Purchases of hydrocarbons

 

We continue purchasing all crude oil delivered to the ANH as royalties by us and by third parties. The purchase price is calculated according to a formula set forth in a contract between us and the ANH that reflects our export sales prices (crudes and products), a quality adjustment for API gravity and sulfur content, transportation rates from the wellhead to the Coveñas and Tumaco ports and a marketing fee. We sell the physical product purchased from the ANH as part of our ordinary business. In June 2015, the contract between the ANH and us was extended until June 30, 2016.

 

Our purchases of hydrocarbons from the ANH are made in the ordinary course of business, and on terms comparable to those offered to private parties. We have established procurement policies and approval processes for purchases of products and services, which do not depend on whether the counterparties are state-owned entities.

 

4.2Effect of Taxes, Exchange Rate Variation, Inflation and the Price of Oil on our Results

 

4.2.1Taxes

 

In December 2014, the Colombian Congress adopted Law 1739 of 2014, a new tax reform which introduced significant changes to the Colombian tax system, including the following:

 

·Wealth Tax a new tax that will be levied from 2015 to 2017 on domestic and foreign companies that, as of January 1, 2015, hold net wealth for tax purposes (assets less allowable liabilities) in Colombia in excess of COP$1 billion. The applicable rates for this wealth tax are: 1.15% for 2015, 1% for 2016, and 0.4% for 2017, subject to certain exceptions.

 

·CREE tax rate (“Impuesto sobre la renta para la Equidad or income tax for equality). The tax reform makes the CREE tax rate of 9% permanent.

 

·CREE surtax– a new surcharge for corporations and entities whose net income for fiscal years 2015 to 2018 is equal to or greater than COP$800 million. The applicable rates for the CREE surtax are: 5% for 2015, 6% for 2016, 8% for 2017 and 9% for 2018.

 

As a result of these tax changes, the overall statutory corporate income tax rate from 2015 to 2018 is expected to be as follows: 39% in 2015, 40% in 2016, 42% in 2017 and 43% in 2018. 

 

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Effect on other taxes

 

The tax reform of 2014 discussed above has also included other provisions that are relevant to and may impact our results of operations:

 

·An extension of a 0.4% charge on financial transactions (“GMF” for its acronym in Spanish), which will be fully in effect until 2019 and will be progressively reduced from 2020 to 2022.

 

·A provision under which companies will be eligible for a credit against their income tax liability of up to 2% of the VAT paid on the acquisition or importation of capital assets (i.e., tangible and amortizable assets that are not sold or transferred in the ordinary course of business and that are used for the production of goods and/or services).

 

·Limitations on the benefit related to the discounting of VAT accrued and paid on the acquisition or importation of heavy machinery for certain basic industries.

 

·Extension of the current deduction applicable for investments in certain research and development projects as determined by the criteria and conditions established by the Colombian government.

 

·Exchange rate differences on foreign investments in fixed assets are not considered items of income or tax expense until the time of disposal of such investments.

 

·Clarification that the National Gasoline Tax will apply upon the sale, write-off or importation of gasoline, regardless of whether such gasoline is imported for consumption or for sale. Before the tax reform was enacted in 2014, it was not clear whether the importation for sales purposes triggered a taxable event.

 

During 2015, there were no relevant changes in the Colombian tax system.

 

In 2015, we paid income tax and wealth tax of COP$3,148,028 million and COP$649,800 million, respectively. See Note 9 – Taxes to our consolidated financial statements.

 

4.2.2Exchange Rate Variation

 

Our results are reported in Colombian Pesos, and we maintain our financial books and records in Colombian Pesos. However, a substantial part of our revenues from local sales and exports of crude oil, natural gas and refined products are sold at prices referenced to benchmarks quoted in U.S. dollars. Therefore, we are exposed to foreign currency exchange risk on revenues, capital expenditures and financial instruments that are denominated in a currency other than our functional currency (Colombian Pesos).

 

An appreciation of the Colombian Peso has a negative impact on our results of operations because our revenues from exports of crude oil, natural gas and refined products are primarily expressed in Colombian Pesos. Costs of imported goods and contracted services expressed in U.S. dollars will also be lower when expressed in Colombian Pesos, but on balance, our operating income in Colombian Pesos tends to decline when the Colombian Peso appreciates, other factors being equal. Conversely, when the Colombian Peso depreciates against the U.S. dollar, our reported revenues, costs related to imported goods and services, interest costs, and operating income, all tend to increase. As crude oil is priced in U.S. dollars, fluctuations in the exchange rate of the Colombian Peso against the U.S. dollar may have a significant impact on revenues, cost, assets and liabilities held in foreign currency.

 

During 2015 and 2014, the Colombian Peso depreciated on average 37.28% and 7.05%, respectively, against the U.S. dollar. Additionally, as of December 31, 2015 and December 31, 2014, the Colombian Peso depreciated 31.64% and 24.17%, respectively, from the rate a year earlier.

 

In 2015, our consolidated debt in foreign currency increased by a total of US$3,425 million as Ecopetrol S.A. raised US$1,925 million through an international loan and US$1,500 million through an international bond issuance. In 2014, our consolidated debt in foreign currency increased through international bond issuances by Ecopetrol S.A. and Ocensa for a total of US$3,700 million.

 

As of December 31, 2015 our U.S. dollar-denominated total debt was US$14.6 billion, which we recognize in our financial statements at its amortized cost, which corresponds to the present value of cash flows, discounted at the effective interest rate. Out of this total, US$11.1 billion relates to Ecopetrol S.A., whose functional currency is the Colombian Peso. Therefore, when the Colombian Peso depreciates against the U.S. dollar, the Company is exposed to an exchange rate loss. In contrast, when the Colombian Peso appreciates against the U.S. dollar, the Company has an exchange rate gain. Some of Ecopetrol Group affiliates have the U.S. dollar as functional currency, and are not exposed to an exchange rate risk. When we consolidate our financial statements, the exchange rate differential of our affiliates whose functional currency is the U.S. dollar is recognized directly as equity, as part of the other comprehensive income.

 

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As of October 1, 2015, we adopted hedge accounting as part of our risk management strategy, using the natural hedge between exports of crude oil and U.S. dollar-denominated debt. As such, 49% of Ecopetrol S.A.’s debt in dollars was designated as a hedge instrument of our future export sales for the period of 2015- 2023, see Note 4.1.4 to our consolidated financial statements for further explanation of the accounting policy and note 31.2.1 for details of the hedge accounting adopted. With the adoption of hedge accounting, the effect of the volatility of the foreign exchange rate on the hedged portion of the debt is recognized directly in equity, as part of the other comprehensive income. The remaining portion of Ecopetrol S.A.’s U.S. dollar-denominated debt continues to be exposed to the fluctuation in the exchange rate.

 

4.2.3Effects of Inflation

 

Inflation in Colombia has remained relatively stable for the past ten years; however, it did increase significantly in 2015 as compared to 2014. As measured by the general consumer price index, average annual inflation in Colombia for the years ended December 31, 2015 and 2014, inflation was 6.77% and 3.66%, respectively. The increase in inflation in 2015 is mainly explained by the partial pass-through of nominal depreciation to consumer prices and costs of raw materials, as well as by a strong increase in food prices due to “El Niño” weather phenomenon. Cost inflation in the prices of goods, raw materials, interest cost of debt in local currency indexed to inflation and services that are necessary for the development and operation of oil and gas producing assets can vary over time and between each market segment.

 

4.2.4Effects of the Price of Oil

 

The average price of ICE Brent crude was US$53.6 per barrel in 2015 as compared to US$99.3 per barrel in 2014. As a consequence, our average price crude oil basket was US$43.9 per barrel in 2015 and US$87.3 per barrel in 2014, which represents a decrease of US$43.4 per barrel in 2015 compared to 2014. This decline is mainly explained by a continuing imbalance between supply and demand in the global crude market due to higher production in North America as well as the scheduled and unscheduled maintenance at refineries in the United States, Europe and Japan and diminished growth projections for the leading global economies.

 

In the Operating Results section below, we present the impact of the price decline in our revenue and cost of sales.

 

Additionally, the drop in the price of oil has had an impact on the value of our oil and gas reserves. The valuation of these reserves was made using a price in accordance with SEC regulations. In 2015, in connection with the current adverse economic context faced by the hydrocarbons sector, which resulted in a reduction in forecasted oil prices, lower expected refining margins in the coming years and an increase in market and country risk that is reflected in the discount rate, as well as a reduction in the recoverable reserves amount and refining margin, among other factors, Ecopetrol recognized an impairment of non-current assets of COP$7,864,875 million before taxes. For additional information see Risk Review—Risks Related to Our Business—Our crude oil and natural gas reserve estimates involve some degree of uncertainty and may prove to be incorrect over time, which could adversely affect our ability to generate revenue and Notes 14, 18, 19 and 29 to our consolidated financial statements.

 

4.3Accounting Policies

 

4.3.1Adoption of IFRS

 

Our consolidated financial statements for the years ended December 31, 2014 and 2015 were prepared in accordance with IFRS. Our date of transition to IFRS was January 1, 2014. These consolidated financial statements are our first financial statements prepared in accordance with IFRS. As required by IFRS 1—First Time Adoption of International Financial Reporting Standards—our financial position and results of operations for the year ended December 31, 2014 have been restated in accordance with IFRS. Note 35 to our consolidated financial statements contains an analysis of the presentation and disclosure effects of adopting IFRS and the effects on equity and net income for the fiscal year ended December 31, 2014 as of January 1 and December 31, 2014. The selected financial information for 2014 included in this annual report differs from the information we previously published for 2014, because it is presented in accordance with IFRS for comparative purposes, as required by IFRS 1.

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4.4Critical Accounting Judgments and Estimates

 

Critical accounting policies are those policies that require us to exercise judgment or involve a higher degree of complexity in the application of the accounting policies that currently affect our financial condition and results of operations. The accounting judgments and estimates we make in these contexts require us to calculate variables and make assumptions about matters that are highly uncertain. In each case, if we had made other estimates, or if changes in the estimates occur from period to period, our financial condition and results of operations could be materially affected.

 

See Notes 3 and 4 to our consolidated financial statements for a summary of the critical accounting judgments and estimates as well as principal accounting policies and practices applicable to us. There are many other areas in which we use estimates about uncertain matters, but we believe the reasonably likely effect of changed or different estimates would not be material to our financial presentation.

 

4.5Operating Results

 

The following discussion is based on information contained in our audited consolidated financial statements and should be read in conjunction therewith.

 

4.5.1Consolidated Results of Operations

 

The following table sets forth components of our income statement for the years ended December 31, 2015 and 2014.

 

Table 47 – Consolidated Income Statement

Income Statement
(Colombian Pesos in millions)
  For the Year ended December 31,   % Change 
   2015   2014   2015/2014 
Revenue   52,347,271    65,971,888    (20.7)
Cost of Sales   36,994,516    42,975,128    (13.9)
Gross Profit   15,352,755    22,996,760    (33.2)
Operating Expenses   13,221,590    8,547,733    54.7 
Operating Income   2,131,165    14,449,027    (85.3)
Finance results, net   (7,663,104)   (3,510,669)   118.3 
Share of profit of companies   (46,687)   166,070    (128.1)
Income before income tax   (5,578,626)   11,104,428    (150.2)
Income tax   (710,353)   (5,434,855)   (86.9)
Net Income (loss)   (6,288,979)   5,669,573    (210.9)
Net Income (loss) attributable to:               
Owners of Ecopetrol   (7,193,859)   5,046,517    (242.6)
Non-controlling interest   904,880    623,056    45.2 
Net Income (loss)   (6,288,979)   5,669,573    (210.9)

 

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4.5.1.1Total Revenues

 

The following table sets forth our principal sources of third-party revenues by business segment for the years ended December 31, 2015 and 2014. An explanation of how we classify our operations into business segments is included in Section 4.5.2 below.

 

Table 48 – Third-party Revenues by Business Segment

 

   2015   2014   % change sales
revenues
 
Revenue by segment  Volume (barrels
equivalent)
   Average price
U.S. dollars/
barrels
   Sales revenues
(Colombian Pesos
in millions)
   Volume (barrels
equivalent)
   Average price
U.S. dollars/
barrels
   Sales revenues
(Colombian Pesos
in millions)
   2015 - 2014 
Local crude oil   4,904,765    38.5    491,279    8,202,886    74.7    1,213,718    (59.5)
Foreign crude oil   178,581,520    44.0    21,181,265    176,233,111    87.9    30,835,510    (31.3)
Trading of crude oil   17,526,239        1,309,196    17,977,861        1,486,060    (11.9)
Natural gas local   30,831,442    21.8    1,845,345    30,218,758    22.3    1,346,625    37.0 
Foreign natural gas   2,906,034    23.6    182,950    6,726,072    31.0    423,461    (56.8)
Other income(1)   3,558,621        659,178    2,925,769        597,671    10.3 
Exploration and production sales   238,308,621         25,669,213    242,284,457         35,903,045    (28.5)
Local refined products   102,475,029    67.1    18,806,063    94,736,264    111.2    20,952,495    (10.2)
Foreign refined products   26,357,160    48.8    3,535,666    29,762,138    92.5    5,431,828    (34.9)
Other income(1)           115,137            227,881    (49.5)
Refining and petrochemicals   128,832,189         22,456,866    124,498,402         26,612,204    (15.6)
Transportation services            4,221,192             3,456,639    22.1 
Transportation and logistics            4,221,192             3,456,639    22.1 
Total sales   367,140,810         52,347,271    366,782,859         65,971,888    (20.7)
Crude oil   201,012,524    43.9    22,981,740    202,413,858    87.3    33,535,288    (31.5)
Natural gas   33,737,476    22.0    2,028,295    36,944,830    23.9    1,770,086    14.6 
Refined products   132,390,810    63.4    22,341,729    127,424,171    106.8    26,384,323    (15.3)
Other           4,995,507            4,282,191    16.7 
Total sales   367,140,810         52,347,271    366,782,859         65,971,888    (20.7)

 

 

Note:

All intercompany sales transactions have been eliminated in full in order to show our sales to third parties.

As a result of the evaluation of control over companies under IFRS, Ecopetrol does not consolidate Equion. As a consequence, the volume information for 2014 included in this annual report (which has been prepared under IFRS) differs from the information we previously published for 2014 under Colombian Government Entity GAAP (where we did consolidate Equion).

(1)In the case of the exploration and production segment, corresponds to services and sales of refined products (mainly LPG and asphalt) allocated to our exploration and production segment. In the case of the refining and petrochemicals segment, corresponds to industrial services.

 

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In 2015, total revenues decreased by 20.7% as compared to 2014, primarily as a result of: (i) a COP$27,847,772 million, decrease in revenues mainly due to the 49.7%, or US$43.4 per barrel reduction of our average crude oil basket price. This decrease was offset by (i) the 37.28% devaluation of the Colombian Peso against the U.S. dollar, from an average exchange rate of COP$2,000.68/US$1 in 2014 to an average exchange rate of COP$2,746.47/US$1 in 2015, resulting in an increase in sales revenue from exports as well as in services provided by our transportation and logistics segment, which combined represented an upturn of COP$13,312,094 million and (ii) COP$882,873 million increase in revenues which was attributable to increase our sales volume.

 

The increase of our sales volume was mainly the result of the 3.9%, or 4.97 mbe, increase in our refined products sales volume, which in turn was primarily the result of the 8.2% increase in local sales of refined products given higher demand caused mainly by the increase in the number of vehicles in Colombia, the higher consumption of diesel for energy generation at thermal power plants due to warmer weather caused by the El Niño climate phenomenon and supplying the border area with Venezuela due to that country’s decision to temporarily close its border with Colombia; partially offset by lower exports of fuel oil, as a result of the difficulties in transporting these products to port by means of the Rio Magdalena due to the reduced flow from this river. This increase in sales volume was partially offset by the 56.8%, or 3.8 mbe, decrease in natural gas exports due to the termination of our Venezuela sales contract on June 30, 2015 and the natural decline in production at the Guajira field.

 

4.5.1.2Cost of Sales

 

Our cost of sales was principally affected by the factors described below. See Note 27 Cost of sales to our consolidated financial statements for more detail.

 

Cost of sales in 2015 was COP$36,994,516 million, representing a COP$5,980,612 million (13.9%) decrease as compared to 2014, primarily as a result of the following factors:

 

·COP$4,900,941 million decrease in the purchase costs of crude oil, natural gas and refined products (primarily diluents, diesel and gasoline), which were purchased for sales and in the case of raw materials for refining, which was primarily the result of lower average purchase prices due to the COP$12,068,310 million decrease in international benchmark prices for crude oil, natural gas and refined products. This decrease was partially offset by (i) a COP$5,156,625 increase in the average exchange rate of the Colombian Peso against the U.S. dollar (which led to increased costs in Colombian Peso terms) and (ii) a COP$2,010,744 million increase in volumes purchased from third parties, primarily consisting of increased purchases of gasoline volumes due to the closing of the Cartagena refinery for most of the year and increased local demand in Colombia caused by an increased number of automobiles and the closure of Colombia’s border with Venezuela.

 

·A COP$898,407 million decrease in maintenance and contracted services cost, which was primarily the result of (i) a COP$585,705 million decrease in contracted services, mainly due to cost savings achieved through the implementation of our business transformation plan, operating cost optimizations contained in our partnership contracts for the Rubiales, Nare and Quifa fields, and lower costs related to the Cravo Norte field, in which our participation in 2015 was lower than in 2014; and (ii) a COP$312,702 million decrease in maintenance costs, mainly due to savings achieved from our 2015 maintenance plan, which included the restructuring of maintenance services and quantities and the renegotiation of fees for field maintenance contracts.

 

·A COP$357,835 million decrease in cost of sales, which was primarily the result from the accumulation of inventories due to the start-up of Reficar’s operations.

 

·A COP$94,625 million decrease in transportation costs, which was primarily the result of decreased use of tanker trucks as a result of the increased availability of pipelines due to greater operating stability and improved security conditions during 2015, which led to a decrease in attacks on our infrastructure.

 

·A COP$70,032 million decrease in other minor items.

 

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The factors mentioned above were partially offset by a COP$341,228 million increase in the amortization, depletion and depreciation of property, plant and equipment, primarily as a result of higher investments in the Castilla, Chichimene, and Rubiales fields.

 

4.5.1.3Operating Expenses

 

Operating expenses and selling, general and administrative expenses amounted to COP$13,221,590 million in 2015, a COP$4,673,857 million (54.7%) increase as compared to 2014, mainly as a result of the following factors (see Notes 28 and 29 to our consolidated financial statements for more detail).

 

·A COP$5,560,308 million increase in the impairment of our non-current assets, of which COP$4,819,998 million related to property, plant and equipment and natural resources and COP$740,310 million related to investments in companies and good will. The impairment of property, plant and equipment and natural resources was mainly due to the existing low oil price environment, which has resulted in a reduction in forecasted crude oil prices and an increase in market and country risk, which has been reflected in the discount rate, as well as a reduction in the amount of recoverable reserves. These impairments are an accounting effect that does not involve any disbursement of resources. For more information see Notes 14, 18, 19 and 29 to our consolidated financial statements as well as our result of operations by segment below.

 

·A COP$628,813 million increase in taxes mainly due to the wealth tax applicable for the year 2015 whereas no accrual was made for wealth tax expenses in 2014.

 

This increase was partially offset by:

 

·A COP$992,045 million decrease in exploratory expenses as a result of decreased seismic activity and fewer dry wells reported in the period;

 

·A COP$365,786 million decrease in general expenses due to optimization in commissions fees, services and agreements achieved through the implementation of the transformation program; and

 

·A COP$157,433 million decrease in other minor items.

 

Each of our operating segments bears the costs and expenses incurred for product use and marketing and each segment assumes administrative expenses and all non-operational transactions related to its activity. Discussion of operating expenses by business segment is included in the section Financial Review—Operating Results—Consolidated Results of Operations—Segment Performance and Analysis.

 

4.5.1.4Finance Results, Net

 

Financial results, net, mainly includes the exchange rate gains or losses and interest expense, yields and interest from our investments, non-current liabilities financial costs (asset retirement obligation and post-benefits plan) and results from our hedging operations. Finance results, net, amounted to a loss of COP$7,663,104 million in 2015 as compared to a loss of COP$3,510,669 million in 2014. This increase in loss was mainly due to:

 

·The negative impact (COP$3,296,421 million) resulting from the depreciation of the Colombian Peso against the U.S. dollar on our U.S. dollar net liability position. Our 2015 exchange rate loss was COP$5,566,614 million, as compared to a loss of COP$2,270,193 million in 2014.

 

·A COP$1,007,362 million increase in financial expenses due to higher interest expenses as a result of the US$1,925 million international loan we entered into in February 2015 and the US$1,500 million international bond we issued in June 2015 as well as the negative effect the Colombian Peso had on our exchange rate on interest due on our foreign debt.

 

This increase in our financial loss was partially offset by (i) a COP$110,600 million increase in revenues resulting from the sale of shares in Empresa de Energía de Bogotá and dividends received from equity instruments and (ii) a COP$40,748 million decrease in other minor financial expenditures.

 

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For more details on our financial income and expenses see Note 30 – Finance results, net to our consolidated financial statements.

 

4.5.1.5Income Tax

 

Income taxes amounted to COP$710,353 million in 2015, which is equivalent to an effective tax rate of (12.7%). In 2014, income taxes amounted to COP$5,434,855 million in 2014, which is equivalent to an effective tax rate of 48.9%.

 

The decrease in the effective tax rate from 2014 to 2015 was mainly due to: (i) foreign exchange losses and a related adjustment for foreign currency translation, (ii) an adjustment to the tax rate of entities whose tax rate differed from that of Ecopetrol S.A. and (iii) the implementation of a nondeductible wealth tax in 2015.

 

See Note 9 –Taxes to our consolidated financial statements.

 

4.5.1.6Net Income (Loss) Attributable to Owners of Ecopetrol

 

As a result of the foregoing, in 2015, net loss attributable to owners of Ecopetrol was COP$7,193,859 million whereas, in 2014, net income attributable to owners of Ecopetrol was COP$5,046,517 million.

 

4.5.1.7Segment Performance and Analysis

 

In this section, including the tables below, we present our financial information by segment: Exploration and Production, Refining and Petrochemicals and Transportation and Logistics. See the section Business Overview for a description of each segment.

 

The following tables present our revenues and net income by business segment for the years ended December 31, 2015 and 2014:

 

Table 49 – Revenues by Business Segment

 

   Year ended December 31,   % change 
Revenues by segment  2015   2014   2015 - 2014 
   (Colombian Pesos in millions)     
Exploration and Production   31,732,611    45,155,191    (29.7)
Third parties   25,669,213    35,903,045    (28.5)
Local crude oil   491,279    1,213,718    (59.5)
Foreign crude oil   21,181,265    30,835,510    (31.3)
Trading of crude oil   1,309,196    1,486,060    (11.9)
Natural gas local   1,845,345    1,346,625    37.0 
Foreign natural gas   182,950    423,461    (56.8)
Other income   659,178    597,671    10.3 
Inter-segment net operating revenues   6,063,398    9,252,146    (34.5)
Refining and Petrochemicals   23,245,676    27,172,300    (14.5)
Third parties   22,456,866    26,612,204    (15.6)
Local refined products   18,806,063    20,952,495    (10.2)
Foreign refined products   3,535,666    5,431,828    (34.9)
Other income   115,137    227,881    (49.5)
Inter-segment net operating revenues   788,810    560,096    40.8 
Transportation and Logistics   10,844,550    8,343,934    30.0 
Third parties   4,221,192    3,456,639    22.1 
Inter-segment net operating revenues   6,623,358    4,887,295    35.5 
Eliminations of consolidations   (13,475,566)   (14,699,537)   (8.3)
Total revenues   52,347,271    65,971,888    (20.7)

 

Total revenues by segment include exports and local sales to third-parties and inter-segment sales. See the section Financial Review—Operating Results—Consolidated Results of Operations—Total Revenues for prices and volumes to third parties.

 

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Table 50 – Net Income by Business Segment

 

   Year ended December 31,   % change 
Net income by segment  2015   2014   2015-2014 
   (Colombian Pesos in millions)     
Exploration and Production   (5,851,619)   5,089,841    (215)
Refining and Petrochemicals   (4,016,050)   (1,627,705)   147 
Transportation and Logistics   2,819,759    1,758,777    60 
Eliminations of consolidations   (145,949)   (174,396)   (16)
Net Income attributable to owners of Ecopetrol S.A.   (7,193,859)   5,046,517    (243)

 

4.5.1.8Exploration and Production Segment Results

 

In 2015, exploration and production segment sales were COP$31,732,611 million, compared to COP$45,155,191 million in 2014. In 2015, our segment sales decreased by 29.7 % as compared with 2014 mainly as a result of:

 

·Lower sales of crude oil to third parties, which decreased by 28.5% in 2015 as compared to 2014 primarily due to: (i) a decline in crude oil exports mainly due to a decrease in the price of our crude oil basket of US$43.9 per barrel, (ii) decreased local sales of crude oil mainly due to lower prices of crude oil and (iii) increased availability of our transport systems for foreign crude oil. The decrease in sales of crude oil to third parties was offset by an increase in our sales volume, particularly in respect of natural gas sales mainly due to increased demand from domestic thermal power plants as a result of the El Niño climate phenomenon, which resulted in lack of water in for the hydroelectric generating plants; and

 

·Lower inter-segment sales, which decreased by 34.5% mainly due to: (i) lower prices of oil and gas sold to our refining and petrochemical segment and (ii) a greater percentage of oil purchased from third parties in the mix used in the Barrancabermeja refinery.

 

Cost of sales affecting our exploration and production segment is mainly related to: (i) the amortization and depletion of our production assets, (ii) contracted services in partnership contracts and (iii) the costs related to maintenance, operational services, projects and labor in the exploration and production segment. In addition, this segment’s costs are impacted by imported naphtha for dilution and by transportation services.

 

In 2015, the cost of sales for this segment decreased by 8% as compared with 2014, due to the net effect of:

 

·Fixed costs increasing by 6.2%, or COP$420,083 million, in 2015 as compared to 2014, mainly due to a COP$860,539 million increase in the costs of hydrocarbon transportation services as a result of a ship or pay contract, indexed to the U.S. dollar, between the exploration and production and transportation and logistics segments of the Bicentenario pipeline, offset by COP$440,456 decrease in maintenance and contracted services cost as a result of the implementation of our business transformation plan.

 

·Variable costs decreasing by 12.5%, or COP$2,638,994 million, in 2015 as compared to 2014, as a result of (i) lower costs related to our purchases crude oil from the ANH and third parties as well as our purchases of refined products, in each case due to a decrease in international prices, and (ii) cost savings from our renegotiation of rates in some of our contracts.

 

In 2015, operating expenses increased by 47.2% in 2015 as compared to 2014, primarily as a result of increased impairment charges for non-current assets, which totaled COP$4,504,496 million as compared to COP$965,607 million in 2014 due to the existing low oil price environment, which has resulted in a reduction in forecasted crude oil prices and an increase in market and country risk, which has been reflected in the discount rate, as well as a reduction in the amount of recoverable reserves. The most significant cash generation units impacted by the impairments were the following fields: in Colombia, Chichimene, Tibú, CP09, Apiay, Llanito and La Hocha and in the Gulf of Mexico, K2 and Dalmatian (see Notes 14, 18, 19 and 29 to our consolidated financial statements). Our operating expenses in this segment also increased due to the Colombian wealth tax. This increase was partially offset by (i) lower expenses related to our exploratory activity as we engaged in less seismic activity and exploratory drilling, (ii) a decrease in commissions, fees, freight and services as a result of cost savings related to our transformation program, and (iii) the recovery of provisions for litigation related to the payment of an electric-power-generation contribution by Ecopetrol S.A. and compensation to third parties for infringement of the free competition clause in the Garcero association contract (see Note 23 to our consolidated financial statements for more detail).

 

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The segment recorded net loss attributable to owners of Ecopetrol of COP$5,851,620 million in 2015 as compared to a net income attributable to owners of Ecopetrol of COP$5,089,841 million in 2014.

 

Lifting and Production Costs

 

The aggregate average production cost, on a Colombian Peso basis, has decreased to COP$21,732 per boe during 2015 from COP$24,872 per boe during 2014, primarily due to:

 

·The execution of our program for reducing operating costs as well as the implementation of our transformation program. The key optimization strategies contributing to decreased production costs are:

 

i)Renegotiation of contracts, representing an approximate 30% optimization in our fields’ operations and services.
ii)Fewer and shorter well interventions.
iii)Less frequent operational maintenance, due to improved maintenance routines and equipment reliability.
iv)Lower consumption of chemicals, as a result of greater processing efficiency and a decrease in chemical treatment fees through renegotiated contracts.
v)Optimization of our fields’ energy fees, due to replacement of our power generation systems with more cost-effective systems and connecting them to the national power grid.

 

·An increase in production volumes in direct and associated contracts (excluding production tests and discovery of undeveloped fields), mainly explained by better production primarily in the Castilla and Chichimene fields and partially offset by a decrease in production volumes from fields in held as part of a partnership, primarily the Rubiales and Quifa fields due to lower development investments on account of lower international prices in 2015 as compared to 2014.

 

As a result of the above-mentioned factors, our aggregate average lifting cost, on a Colombian Peso basis, decreased in 2015 as compared to 2014. On a dollar basis, it decreased to US$7.92 per boe in 2015 from US$12.43 per boe in 2014 also due to a 37.1% depreciation of the average exchange rate of the Colombian Peso against the U.S. dollar in 2015.

 

The difference between the aggregate average lifting cost and aggregate average production cost is that lifting costs do not include the costs related to consumption of hydrocarbons by us in our production process or that Ecopetrol sold to our refineries and natural gas liquid plants.

 

The following table sets forth crude oil and natural gas average sales prices, the aggregate average lifting costs and aggregate average unit production cost for the years ended December 31, 2015 and 2014.

 

Table 51 – Crude Oil and Natural Gas Average Prices and Costs

 

   2015   2014 
Crude Oil Average Sales Price (U.S. dollars per barrel)(1)   43.9    87.3 
Crude Oil Average Sales Price (COP$ per barrel)(1)   118,115    173,769 
Natural Gas Average Sales Price (U.S. dollars per barrel equivalent)   22.0    23.9 
Natural Gas Average Sales Price (COP$ per barrel equivalent)   60,120    47,912 
Aggregate Average Unit Production Costs (U.S. dollars per boe)(2)   7.92    12.43 
Aggregate Average Unit Production Cost (COP$ per boe)(2)   21,732    24,872 
Aggregate Average Lifting Costs (U.S. dollars per boe)(3)(4)(5)   7.40    11.29 
Aggregate Average Lifting Costs (COP$ per boe)(3)(4) (5)   20,308    22,581 

 

 

(1)Corresponds to our average sales price on a consolidated basis.
(2)Unit production costs correspond to consolidated average costs on total production volumes net of royalties. Production costs do not include costs related to transport, commercialization and administrative expenses.
(3)Lifting costs per barrel are calculated based on total production (excluding production tests and discovered undeveloped fields), which are net of royalties, and correspond to our lifting costs on a consolidated basis.
(4)The cost indicator is calculated by using the cost of production (does not include costs related to hydrocarbons consumption by Ecopetrol in the production process, such as by our refineries and natural gas liquid plants) and dividing by the net produced volume (excluding royalties) as the denominator.
(5)As a result of the evaluation of control over companies under IFRS, Ecopetrol does not consolidate Savia Perú and Equion. As a consequence, the information in the table above for this annual report (which has been prepared under IFRS) differs from the information we previously published for 2014 under Colombian Government Entity GAAP (where we did consolidate Savia Perú and Equion).

 

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4.5.1.9Transportation and Logistics Segment Results

 

In 2015, our transportation and logistics segment sales were COP$10,844,550 million compared to COP$8,343,934 million in 2014. This 30% increase in 2015 as compared with 2014 was mainly due to higher volume of crude oil transported by the Ocensa, Caño Limón Coveñas and Oleoducto Transandino pipelines due to the decline in the number of attacks on our infrastructure and the positive effect on our U.S. dollar-indexed transportation fees resulting from the devaluation of the Colombian Peso against the U.S. dollar.

 

The cost of sales for our transportation and logistics segment is mainly related to: (i) project costs associated with the maintenance of transportation networks and (ii) operating costs related to these systems, including the costs of labor, energy, fuels and lubricants and others.

 

The cost of sales amounted to COP$3,744,422 million in 2015 and COP$3,941,052 million in 2014. The cost of sales for this segment decreased by 5% in 2015 as compared with 2014 mainly due a decrease in costs associated with maintenance and operating supplies and materials. This decrease was partially offset by an increase in depreciation and amortization due to our increased investments in this segment.

 

In 2015, operating expenses decreased by 4.2% as compared to 2014 due to decreased expenses related to social investment and security agreements, and more stable operations due to a decrease in repairs of our transportation systems. This decrease was partially offset by (i) the Colombian wealth tax implemented in 2015, (ii) increased depreciation and amortization and (iii) increased impairment charges for assets primarily to Colombia’s hydrocarbon production curves, based on the current crude oil price environment and pipeline transportation rates (see Notes 14, 18, 19 and 29 to our consolidated financial statements).

 

The segment recorded a net income attributable to owners of Ecopetrol of COP$2,819,759 million in 2015 and COP$1,758,777 million in 2014.

 

4.5.1.10Refining and Petrochemicals Segment Results

 

In 2015, the refining and petrochemical segment sales were COP$23,245,676 million compared to COP$27,172,300 million in 2014. In 2015, sales of refined products and petrochemicals decreased by 14.5% as compared with 2014, mainly due to: (i) a decrease in the international price of fuels and (ii) a decrease in foreign sales volumes of fuel oil due to the low water level in the Rio Magdalena. This decrease was partially offset by (i) an increase in the volume of domestic sales due to increased local demand for fuel resulting from an increased number of vehicles and the closure of Colombia’s border with Venezuela and (ii) an increase in intercompany sales due to higher volumes of diluent sold to our exploration and production segment.

 

The cost of sales for our refined products and petrochemicals segment is mainly related to the purchase of crude oil and natural gas for our refineries, imported products to substitute for the loss of production due to the shutdown of Reficar for most of 2014 and 2015, feedstock transportation services, services contracted for maintenance of the refinery and the amortization and depreciation of refining assets. Cost of sales amounted COP$20,758,808 million in 2015 compared to COP$25,537,228 million in 2014.

 

In 2015, the cost of sales for this segment decreased 18.7% as compared with 2014, principally due to lower raw material costs, which corresponded to the decrease in international oil prices and lower operating costs as a result of cost optimization at the Barrancabermeja Refinery. This decrease was partially offset by higher imports of gasoline due to increased local demand for fuel resulting from an increased number of vehicles and the closure of Colombia’s border with Venezuela.

 

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In 2015, operating expenses increased by 85% as compared to 2014 due to:

 

·Increased impairment charges for non-current assets recorded by the Cartagena Refinery due to the current low oil price environment, which resulted in a reduction in expected refining margins in the coming years, and an increase in market and country risk, which has been reflected in the discount rate, (see Notes 14, 18, 19 and 29 to our consolidated financial statements). The variables that impact the impairment of long-term assets are mainly the refining margin, the discount rate, the cost structure and the level of capital expenditures, of these variables, the refining margin and the discount rate are the most sensitive variables for determining any possible impairment.

 

·Higher levels of investment for the Reficar modernization project.

 

·The Colombian wealth tax implemented in 2015.

 

·An increase in other expenses related to the start-up of operations at Reficar.

 

The gross margin in 2015 was 10.7%, compared to 6% in 2014. The increase in the gross margin was explained principally by decrease in the oil price (feedstock) compared to the decrease in fuel prices (output).

 

The refining and petrochemicals segment recorded a net loss attributable to owners of Ecopetrol of COP$4,016,050 million in 2015 and COP$1,627,705 million in 2014.

 

4.6Liquidity and Capital Resources

 

Our principal sources of liquidity in 2015 were cash flows from our operations amounting to COP$10,411,475 million, and cash flows from financing activities, mainly from the proceeds of our additional indebtedness, which totaled COP$6,082,341 million.

 

Our principal uses of liquidity in 2015 were COP$14,251,509 million in capital expenditures, which included (i) investment in property, plant and equipment and natural and environmental resources and (ii) dividend payments for the fiscal year 2014 amounting to COP$5,493,400 million.

 

On January 29, 2016, we entered into an international credit agreement in an aggregate amount of US$175 million with The Bank of Tokyo-Mitsubishi UFJ, Ltd. The credit agreement has a term of 5 years, repayable with a 2.5 year grace period on principal and interest, payable semi-annually at a rate of Libor plus 145 basis points.

 

On February 23, 2016, we entered into a bilateral commercial loan agreement with Bancolombia S.A. for COP$990 billion (approximately US$314 million at the representative exchange rate of COP$3,149.47 per dollar as of December 31, 2015). This loan agreement has a term of 8 years and a 2-year grace period on principal, with interest payable semiannually at a rate of DTF TA plus 560 basis points.

 

4.6.1Review of Cash Flows

 

Cash from operating activities

 

Net cash provided by operating activities decreased by 37.2% in 2015 as compared to 2014, mainly as a result of: (i) a 33.2% decrease in our gross income resulting from the decrease in international prices of crude oil during 2015 and (ii) higher operating expenses due to the Colombian wealth tax implemented and paid in 2015. This decrease was partially offset by a decrease in income tax paid due to the decrease in our income before tax for the year and lower working capital needs due to a decrease in inventories, trade receivables and accounts payable.

 

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Cash used in investing activities

 

In 2015, net cash used in investing activities decreased by 0.2% as compared to 2014, mainly as a result of: (i) a decrease in the amount of dividends we received from associates and joint ventures companies (ii) slightly larger investments in capital expenditures, mainly relating to the Reficar modernization project and our drilling campaigns, primarily in the Castilla, Chichimene and Rubiales fields, and (iii) a lower net cash contribution from purchase and sale of fixed income investments. This decrease was partially offset by cash proceeds from the sale of our investment in Empresa de Energia de Bogotá, which totaled COP$613,998 million.

 

Cash used in financing activities

 

Net cash used in financing activities decreased by 81% in 2015, as compared to 2014, due to a COP$7,023,166 million decrease in dividend payments, which was partially offset by an increase in borrowing and interest payments of COP$1,069,146 million in 2015 as compared to 2014, which in turn was due to the US$1,925 million international loan we entered into in February 2015 and the US$1,500 million international bond we issued in June 2015.

 

4.6.2Capital Expenditures

 

The following table sets forth our consolidated capital expenditures for each of our business segments for 2015 and 2014.

 

Table 52 – Capital Expenditures

 

   For the year ended December 31, 
   2015   2014 
   (Colombian Pesos in millions) 
Exploration and Production   8,548,933    8,923,568 
Refining and Petrochemicals   5,590,321    5,038,296 
Transportation and Logistics   112,255    112,018 
Total   14,251,509    14,073,882 

 

Our investment plan approved for 2016 totals US$4,800 million. The investments will be distributed as follows: 62% for exploration and production, 22% for refining and petrochemicals, 10% for transportation and logistics, and 6% for other investments.

 

The resources required for the investment plan will be funded through internal cash generation, divestment of non-strategic assets and financing. The Company has borrowing capacity, investment grade rating and access to capital markets in Colombia and abroad.

 

The use of these resources for our investment plan will depend on the performance of crude oil prices during the year.

 

4.6.3Dividends

 

In 2015, we paid dividends of COP$5,493,400 million to our shareholders, including the Nation.

 

On March 31, 2016, our shareholders at the ordinary general shareholders’ meeting did not approve a distribution of dividends for 2015 due to the net loss recorded by the Company in 2015.

 

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4.7Summary of Differences between Internal Reporting (Colombian IFRS and IFRS)

 

We prepare our interim and annual financial information in accordance with our internal reporting policies, which follow Colombian IFRS and differ in certain significant aspects from IFRS. The following table sets forth our consolidated net income and equity for years ended December 31, 2015 and 2014, in accordance with Colombian IFRS and IFRS:

 

Table 53 – Consolidated Net Income and Equity

 

   For the year ended December 31,     
   (Colombian Pesos in millions)     
   2015   2014   % Change 
Net income attributable to owners of Ecopetrol (IFRS)   (7,193,859)   5,046,517    (242.6)
Cash flow hedge for future company exports    2,140,553        N/A 
Exchange rate effects on tax bases – Deferred tax    1,065,580    678,983    56.9 
Net income Attributable to owners of Ecopetrol (Colombian IFRS)   (3,987,726)   5,725,500    (169.6)

 

   At December 31,     
   (Colombian Pesos in millions)     
   2015   2014   % Change 
Net Equity (IFRS)   43,100,963    48,534,228    (11.2)
Cash flow hedge for future company exports    (74,259)       N/A 
Exchange rate effects on tax bases – Deferred tax    2,205,064    998,440    120.9 
Net Equity (Colombian IFRS)   45,231,768    49,532,668    (8.7)

 

As noted above, certain differences exist between our net income and equity as determined in accordance with our internal reporting policies, which follow Colombian IFRS, which are used for management reporting purposes, as presented in the business segment information, and our net income and equity as determined under IFRS, as presented in our consolidated financial statements.

 

The primary differences between Colombian IFRS and IFRS as they apply to our results of operations are summarized below:

 

·Cash flow hedge for future company exports.  In September 2015, in order to hedge the effect of exchange rate volatility on Ecopetrol’s foreign currency debt, Ecopetrol’s Board of Directors approved a cash flow hedge for future crude oil exports. According to IAS 39 – Financial Instruments, Ecopetrol implemented this hedge beginning on October 1, 2015, the date on which it formally completed the related hedging documentation.

 

Under Colombian IFRS, the Contaduria General de la Nación (CGN for its acronym in Spanish) issued Resolution 509, which allows companies to apply hedge accounting for non-derivative financial instruments from any date within the transition period or the first period of application of International Accounting Standards in Colombia, even if such company has not yet formally documented the hedging relationship, the objective or the risk management strategy. Under these rules, Ecopetrol applied cash flow hedge accounting from January 1, 2015 in its financial statements under Colombian IFRS.

 

·Exchange rate effects on tax bases – Deferred tax.  As a result of these accounting policy differences, for the year ended December 31, 2015, our net loss as reported under IFRS was COP$2,140,553 million higher than our net loss as reported under Colombian IFRS. According to IAS 12.41, companies with a U.S. dollar functional currency and profit or tax loss in Colombian Pesos are required to recognize deferred taxes attributable to the difference between the carrying amounts of non-monetary assets in their financial statements and their respective tax bases converted from Colombian Pesos to U.S. dollars using the exchange rate on the closing date. The effect of the temporary difference is charged to profit and losses without a cash outflow expected in the future. Under local accounting principles, the result attributable to the aforementioned difference in accounting policies does not generate deferred taxes at December 31, 2015.

 

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Ecopetrol’s functional currency is the Colombian Peso and it consolidates some subsidiaries whose functional currency is the U.S. dollar but who settled their taxes in Colombian Pesos. As a result of the application of paragraph 41 – IAS 12, such subsidiaries are required to calculate deferred taxes under IFRS.

 

As a result of these accounting policy differences, for the year ended December 31, 2015, our net loss as reported under IFRS was COP$1,065,580 million higher than our net loss as reported under Colombian IFRS.

 

The application of IAS12.41 also generated adjustments to our goodwill impairments of COP$418,872 million taken in connection with our purchase of subsidiaries whose functional currency is the U.S. dollar as well as adjustments to our revenue from the equity method of COP$81,808 million in connection with our associates and joint ventures whose functional currency is the U.S. dollar.

 

As a result of these accounting policy differences described above, for the year ended December 31, 2015, we reported net loss under IFRS of COP$7,193,859 billion as opposed to a net loss of a COP$3,987,726 million reported under Colombian IFRS for the same period.

 

4.8Financial Indebtedness and Other Contractual Obligations

 

As of December 31, 2015, we had outstanding consolidated indebtedness of COP$52,252 billion, which corresponded primarily to the following long-term transactions:

 

Table 54 – Consolidated Financial Indebtedness

 

Company   Type   Initial Date   Original Amount   Maturity   Interest
Rate
  Amortization
Ecopetrol S.A.   Bonds   July 23, 2009   US$1,500 million   July 23, 2019   7.625%   Bullet
        September 18, 2013   US$350 million   September 18, 2018   4.250%   Bullet
        September 18, 2013   US$1,300 million   September 18, 2023   5.875%   Bullet
        September 18, 2013   US$850 million   September 18, 2043   7.375%   Bullet
        May 28, 2014   US$2,000 million   May 28, 2045   5.875%   Bullet
        September 16, 2014   US$1,200 million   January 16, 2025   4.125%   Bullet
        December 1, 2010   COP$138,700 million   December 1, 2017   Floating   Bullet
        December 1, 2010   COP$479,900 million   December 1, 2020   Floating   Bullet
        December 1, 2010   COP$284,300 million   December 1, 2040   Floating   Bullet
        August 27, 2013   COP$120,950 million   August 27, 2018   Floating   Bullet
        August 27, 2013   COP$168,600 million   August 27, 2023   Floating   Bullet
        August 27, 2013   COP$347,500 million   August 27, 2028   Floating   Bullet
        August 27, 2013   COP$262,950 million   August 27, 2043   Floating   Bullet
        June 26, 2015   US$1,500 million   June 26, 2026   5.375%   Bullet
    Bank Loan*   May 27, 2013   COP$1,839 billion   May 27, 2025   Floating   Semi-annual
        March 22, 2013   US$245 million   July 25, 2023   Floating   Semi-annual
        March 22, 2013   US$151 million   July 6, 2019   Floating   Semi-annual
Reficar   Project Finance   December 30, 2011   US$3,497 million   December 20, 2027   Floating / Fixed   Semi-annual
Ocensa   Bond   May 7, 2014   US$500 million   May 7, 2021   4.000%   Bullet
Oleoducto Bicentenario   Bank Loan   July 5, 2012   COP$2,100 billion   July 5, 2024   Floating   Quarterly
ODL   Bank Loan*   August 1, 2013   COP$647,029 million   August 1, 2020   Floating   Quarterly

 

 

* Bank loans were refinanced from their original conditions.

 

The long term debt transactions executed in 2015 were as follows:

 

·On February 12, 2015, Ecopetrol S.A. obtained a US$1.925 billion credit facility. The transaction was accomplished with the participation of eight international banks. The credit facility has a five-year tenor, with a bullet repayment and semiannual interest payments at a rate of LIBOR plus 140 basis points.

 

·The issuance by Ecopetrol S.A. of US$1,500 million (COP$4,723 billion according to the COP$/US$ exchange rate as of December 31, 2015) aggregate principal amount of SEC-registered 5.375% Notes due 2026, issued in June 2015. The notes were listed on the NYSE.

 

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Contractual Obligations

 

We enter into various commitments and contractual obligations that may require future cash payments. The following table summarizes our contractual obligations as of December 31, 2015.

 

Table 55 – Our Contractual Obligations

 

COP$ in millions  Payments due by period 
Contractual obligations  Total   Less than 1
year
   1 to 3 years   3 to 5 years   More than 5
years
 
Employee Benefit Plan   25,565,984.16    1,070,781.40    2,243,236.41    2,323,207.73    19,928,758.63 
Contract Service Obligations   7,346,763.69    3,701,104.57    2,714,700.90    635,434.90    295,523.31 
Operating Lease Obligations   753,609.87    366,820.45    172,196.30    120,109.01    94,484.10 
Natural Gas Supply Agreements   2,345,919.82    269,039.40    495,679.30    396,470.20    1,184,730.92 
Purchase Obligations   3,532,384.45    2,845,906.32    666,633.13    19,845.00    - 
Energy Supply Agreements   969,027.07    143,709.38    335,913.19    96,225.13    393,179.36 
Capital Expenditures   1,406,392.44    1,234,708.88    162,575.78    9,107.79    - 
Build, Operate, Maintain and Transfer Contracts (BOMT)   604,653.79    97,996.19    155,088.58    105,715.32    245,853.69 
Capital (Finance) Lease Obligations   380,989.44    382.00    5,836.76    37,158.62    337,612.05 
Financial Sector Debt   21,113,931.74    1,601,118.39    2,863,708.87    9,105,237.54    7,543,866.95 
Bonds   30,778,024.00    -    1,361,964.50    5,204,105.00    24,211,954.50 
Total   94,797,680.48    11,331,566.98    11,177,533.73    18,052,616.26    54,235,963.51 

 

4.9Off Balance Sheet Arrangements

 

As of December 31, 2015, we did not have off-balance sheet arrangements of the type that is required to be disclosed under Item 5.E of Form 20-F.

 

4.10Trend Analysis and Sensitivity Analysis

 

Trend Analysis

 

On April 22, 2016, the Board of Directors of Ecopetrol approved an adjustment of the investment plan for 2016 from U.S.$4,800 million to a range between U.S.$3,000 – U.S.$3,400 million. See the section Strategy and Market Overview—Our Corporate Strategy.

 

2016 is a year of transition for the Ecopetrol Group, during which investments will be made to finish transportation projects and complete the start up the new Cartagena Refinery. Starting in 2017, the Company will dedicate a larger portion of its investments to the exploration and production segments.

 

The detail of the investments approved per business segment of Ecopetrol S.A. and its subsidiary companies is as follows:

 

Table 56 – 2016 Investment Plan

 

Business Segment  (Millions of US$)   % Percentage
         
Exploration  $282    9.4%
Production   1,116    37.3%
Transportation and Logistics   433    14.4%
Refining, Petrochemicals, and Biofuels   1,135    37.8%
Others   34    1.1%
TOTAL  $3,000    100%

 

Exploration

 

In the exploration segment, U.S.$282 million has been allocated mainly to the evaluation and appraisal of discoveries and ongoing exploration efforts of Ecopetrol S.A. (approximately U.S.$146 million), Hocol (approximately U.S.$68.7 million), Ecopetrol America Inc. (approximately U.S.$47.3 million), and Ecopetrol Brazil (approximately U.S.$18.3 million).

 

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Production

 

In the production segment, U.S.$1,116 million has been allocated mainly to the execution of development and incremental production projects in the Castilla, Chichimene, Caño Sur, Orinoquia, Yarigui, Piedemonte, Nare CIRA-Infantas, CPI Neiva and Casabe fields (approximately U.S.$605 million). We have also allocated funds for our affiliates and subsidiaries as follows: U.S.$76 million for the operation and maintenance of fields of Ecopetrol America Inc. in the U.S. Gulf of Mexico, U.S.$48.8 million to Hocol and U.S.$27.4 million to Equion.

 

Transportation and logistics

 

In the transportation and logistics segment, US$433 million has been allocated to investments focused on the completion of projects such as P135 Ocensa, San Fernando Monterrey and transportation of heavy crude oils as well as crude oil dilution projects. The segment is seeking a higher efficiency in operations and maintenance practices.

 

Refining, petrochemicals, and biofuels

 

In the refining, petrochemicals, and biofuels segment, US$1,135 million has been allocated to the start-up and stabilization of all of the units of Reficar and programs to improve operations at the Barrancabermeja Refinery through initiatives to increase revenues, improve efficiency and reduce operational costs. It is important to highlight that Ecopetrol S.A. has suspended the Barrancabermeja Refinery Modernization Plan until the oil price environment allows investments to be made in such a major project.

 

Ongoing Trends

 

Based on these investments in the refining and transport segments in 2016, the Company expects to have sufficient capacity in those segments to support its mid-term growth. Therefore, it is expected that close to 90% of total investments from 2017 onwards will be allocated to exploration and production.

 

Our exports, which represented 50% of our total sales in 2015, will continue to be our primary source of revenues. With the operation of all units of Reficar in 2016, Ecopetrol’s trade balance is expected to improve because of reduced imports of gasoline and increased exports of fuels. Reficar’s fuels production is expected to be allocated primarily in the domestic market, with some surplus to be exported.

 

We believe that our strategy of diversifying our export destinations and sales under term contracts with fixed discounts to reference prices will help mitigate the negative impact of the current crude oversupply over the discounts of our export basket. We forecast an average discount of US$10 per barrel compared to ICE Brent crude in 2016.

 

Furthering our focus on efficiency, in 2016, we aim to maintain the savings of US$800 million accomplished in 2015, plus additional savings of around US$492 million as a result of the introduction of new efficiencies.

 

The Company expects to continue the 2016 – 2017 divestment program and raise between US$400 and US$900 million. As of the date of this annual report, the Company is in the process of carrying out the sale of non-strategic assets and shareholdings, such as our stake in ISA, Empresa de Energía de Bogota and Propilco.

 

In order to preserve its investment grade ratings, the Company seeks to maintain financial sustainability and adequate levels of indebtedness. In 2015, Ecopetrol obtained US$3,425 million in financing, while in 2016 the Company has adjusted its financing needs to a range between US$1,500 million and US$1,900 million, of which we have already obtained COP$990 billion (approximately US$314 million at the representative exchange rate of COP$3,149.47/US$1 as of December 31, 2015) from the local bank Bancolombia S.A. plus US$175 million from a line of credit with The Bank of Tokyo-Mitsubishi UFJ, Ltd. The Company will continue monitoring oil price scenarios to make the proper decisions and take preventive actions to ensure financial sustainability in 2016 such as: prioritization of investments associated with regulatory commitments and project completion, temporary closing of producing assets with negative margins, reduction in exploratory activity, redefining and prioritizing maintenance activities and additional austerity measures related to administrative expenses, sponsorships and labor recruitment.

 

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Sensitivity Analysis

 

Sensitivity Analysis of Reserves

 

The following table provides information about the sensitivity analysis conducted on our reserves as of December 31, 2015, taking into account ICE Brent crude oil prices that reasonably reflect management’s view of crude oil prices given prevailing market conditions

 

Table 57 – Sensitivity Analysis of Reserves

 

   Oil (million
barrels)
   NGL (million
barrels)
   Natural Gas
(bcf)
   Total Oil
and Gas
(Mmboe)
 
Reserves as of December 31, 2015   1,166    73    3,479    1,849 
Sensitivity Scenario   1,211    74    3,491    1,897 
Difference (million barrels)   45    1    11    47 
Difference (%)   4    1    0    3 

 

 

The conversion rate used is 5,700 cf = 1 boe.

 

Assumptions for the Sensitivity Analysis of Reserves

 

·The sensitivity of the ICE Brent price index is forecasted to average US$40 per barrel in 2016, US$50 per barrel in 2017, US$55 per barrel in 2018, and US$60 per barrel onwards.

 

·The base scenario on which our sensitivity analysis is made corresponds to our reserves, as of December 31, 2015, as presented elsewhere in this annual report.

 

·Values of our net reserves were estimated using a 10% discount rate.

 

·Other variables such as the operating and capital costs were not varied for purposes of the analysis.

 

·Gas prices were defined by current contractual agreements.

 

Sensitivity Analysis of our Results

 

The following table provides information about the sensitivity of our results as of December 31, 2015, due to variations of US$1 in the price of ICE Brent crude and of 1% in the COP$/US$ exchange rate.

 

Table 58 – Results of Reserves’ Sensitivity Analysis

 

   Income
Statement 2015
  

Income
Statement Case
ICE Brent(1)
US$1

   Difference
Between
Real 2015
and Case
ICE Brent
  

Income
Statement Case
TRM(2)
- 1%

   Difference
Between Real
2015 and
Case TRM
 
   (COP$ in billions) 
Revenue   52,347.27    53,217.49    870.22    52,843.65    496.37 
Cost of sales   36,994.52    37,356.46    361.94    37,266.98    272.47 
Gross Income   15,352.76    15,861.03    508.28    15,576.66    223.91 
Administration expenses   1,700.99    1,700.99    -    1,700.99    - 
Operation and project expenses   4,034.27    4,034.27    -    4,034.27    - 
Impairment of non-current assets   7,864.88    7,864.88    -    7,864.88    - 
Other operating income and expenses, net   (378.54)   (378.54)   -    (378.54)   - 
Operating income   2,131.17    2,639.44    508.28    2,355.07    223.91 
Finance results, net   (7,663.10)   (7,663.10)   -    (7,663.10)   - 
Share of profit of associates and joint ventures   (46.69)   (46.69)   -    (46.69)   - 
Income before income tax   (5,578.63)   (5,070.35)   508.28    (5,354.72)   223.91 
Income Tax   (710.35)   (908.58)   (198.23)   (797.68)   (87.32)
Net Income   (6,288.98)   (5,978.93)   310.05    (6,152.39)   136.58 

 

 

(1)ICE Brent = US$54 per barrel

 

(2)Exchange rate (TRM) = COP$2,743/US$1

 

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Assumptions for the Sensitivity Analysis of our Results

 

·Our sensitivity analysis is based on the Consolidated Statement of Profit or Loss for 2015, as presented elsewhere in this annual report.

 

·The sensitivity of the ICE Brent price index is in reference to an increase of US$1 per barrel of crude oil in the average ICE Brent reference price based on a 365-day year for 2015. Prices assumed correspond to realized prices for crude oil, natural gas and refined products for 2015, adjusted to account for the differences between such realized prices and the ICE Brent reference price.

 

·The sensitivity of our results to changes in the exchange rate is in reference to a 1% average depreciation of the Colombian Peso against the U.S. dollar during 2015. Prices assumed correspond to realized prices of crude oil, natural gas and refined products in 2015 and are expressed for the sensitivity using the adjusted exchange rate (i.e. a 1% average depreciation of the Colombian Peso against the U.S. dollar during 2015).

 

·The income tax for each of our sensitivity analyses (price of ICE Brent and COP$/US$ exchange rate) is estimated using the nominal corporate tax rate of 39% for 2015.

 

The table below sets forth the line items that are being affected by the variation on the reference prices or the average exchange rate.

 

Table 59

 

VARIATION ON ICE BRENT REFERENCE PRICE VARIATION ON AVERAGE EXCHANGE RATE
 
REVENUE
   
Sales of crude oil Sales of crude oil
Sales of refined products Sales of refined products
Sales of natural gas Sales of natural gas
 
COST OF SALES
   
Local purchases from business partners Local purchases from business partners
Local purchases of hydrocarbons from the ANH Local purchases of hydrocarbons from the ANH
Local purchases of natural gas Local purchases of natural gas
Imports of products Imports of products

 

5.Risk Review

 

5.1Risk Factors

 

The risks discussed below could have a material adverse effect, separately or in combination, on our business’s operating results, cash flows, liquidity and financial condition. Investors should carefully consider these risks.

 

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5.1.1Risks Related to Our Business

 

This section describes the most significant potential risks to our business.

 

Our crude oil and natural gas reserve estimates involve some degree of uncertainty and may prove to be incorrect over time, which could adversely affect our ability to generate revenue.

 

Reserves estimates are prepared using generally accepted geological and engineering evaluation methods and procedures. Estimates are based on geological, topographical and engineering facts but also depend on many factors and assumptions, including various assumptions that are based on conditions in existence as of the dates of the estimates. Any material changes in those conditions or other factors affecting those assumptions could impair the quantity and value of our reserves, and actual reserves and production may vary materially from estimates presented in this annual report.

 

Hydrocarbon reserves presented in this annual report were calculated in accordance with SEC regulations. As required by those regulations, reserves were valued based on the unweighted average of closing prices for the first day of each month in the 12-month periods ended December 31, 2015, 2014 and 2013, as well as other conditions in existence at those dates. The average of closing prices of ICE Brent crude oil for the first day of each month in the 12-month period was US$108.32 per barrel in 2013, US$101.80 per barrel in 2014 and US$55.57 per barrel in 2015. Mainly as a result of the pronounced fall in hydrocarbon prices between 2014 and 2015, the Company recognizes in 2015 a reduction in oil and gas proven reserves of 11% as compared to 2014, to 1,849 mmboe in 2015 from 2,084 mmboe in 2014. For more information, see the section Business Overview—Exploration and Production—Reserves.

 

Furthermore, at least once a year, or more frequently if the circumstances require, the Company ascertains whether there are signs of impairment to its assets or cash-generating units (CGUs) due to the difference between the carrying amount of such assets or CGUs as opposed to their recoverable amounts, using reasonable assumptions, based on internal and external factors, which reflect market conditions. The recoverable amount is calculated based on the free cash flow method, discounted at the weighted average capital cost (WACC). Whenever the recoverable amount of an asset or CGU is lower than its net carrying amount, such amount is reduced to its recovery amount, recognizing a loss for impairment as an expense in the consolidated statement of profit or loss.

 

In 2015, in connection with the current adverse economic context faced by the hydrocarbons sector, which resulted in a reduction in forecasted oil prices, lower expected refining margins in the coming years and an increase in market and country risk that is reflected in the discount rate, as well as a reduction in the recoverable reserves amount, among other factors, Ecopetrol recognized an impairment of non-current assets of COP$7,864,875 million before taxes. For additional information about this impairment loss, see Notes 14, 18, 19 and 29 to our consolidated financial statements.

 

Any significant change in estimates and judgments could have a material effect on the quantity and present value of our proved reserves and subsequently on the recognition or recovery of impairment charges. Changes to estimations of reserves are applied prospectively to the amounts of depreciation, depletion and amortization charged and, consequently, the carrying amounts of exploration and production assets.

 

The average benchmark closing prices of ICE Brent crude oil for the first day of the first four months of 2016 was US$35.30 per barrel. In order to assess the possible impact of current expected oil price scenarios and market conditions, as well as of further developments driven by the economic environment for the oil and gas industry, the Company has performed a sensitivity analysis over its proved reserve balance as of December 31, 2015. Based on these calculations, assuming an average price per barrel of ICE Brent crude oil of US$40 per barrel in 2016, US$50 per barrel in 2017, US$55 per barrel in 2018, and US$60 per barrel for later years, Ecopetrol could recognize an increase in oil and gas proved reserves of approximately 3%. This analysis takes into account Ecopetrol’s estimates and expectations regarding the main assumptions used in its proven reserve calculation, which final actual result may fluctuate and differ substantially from those provided herein due to several factors outside of the control of the Company. For additional information see the section Financial Review—Trend Analysis and Sensitivity Analysis.

 

Moreover, any downward revision in our estimated quantities of proved reserves would indicate lower future production volumes, which could result in higher expenses for depreciation, depletion and amortization for properties to which we apply the units of production method for calculating these expenses. These higher expenses, and any lower revenues as a result of actual production volumes and realized prices, could adversely impact our results of operations and financial condition.

 

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Achieving our long-term growth prospects depends on our ability to execute our strategic plan — specifically, the discovery and successful development of additional reserves.

 

Our long-term growth objectives depend largely on our ability to discover and/or acquire new reserves, and in turn successfully develop them and to improve the recovery factor in our mature oil fields. Our exploration activities expose us to the inherent risks of drilling including the risk that we will not discover commercially productive crude oil or natural gas reserves; and the risk that some exploratory wells initially budgeted for may be drilled at a later stage or not be drilled at all. The costs associated with drilling wells are often uncertain, and numerous factors beyond our control may cause drilling operations to be curtailed, delayed or cancelled.

 

Our ability to add and develop reserves also depends on our capacity to structurally reduce costs to maintain the profitability of oil fields already being exploited.

 

If we are unable to successfully discover and develop additional reserves, or if we do not acquire properties having proved reserves, our level of proved reserves will decline. Failure to secure additional reserves may impede us from achieving or maintaining production targets, and may have a negative impact on our results of operation and financial condition.

 

See the section Strategy and Market Overview—Our Corporate Strategy for a discussion of our strategic plan.

 

Our business depends substantially on international prices for crude oil and refined products. The prices for these products are volatile; a sharp decrease could adversely affect our business prospects and results of operations.

 

In 2015, in Ecopetrol, nearly 91.5% of the revenues came from sales of crude oil, natural gas and refined products and 90.7% of the total volume sold of these products is indexed to international reference prices or benchmarks such as ICE Brent. Consequently, fluctuations in those international indexes have a direct effect on our financial condition and results of operations.

 

Prices of crude oil, natural gas and refined products have traditionally fluctuated as a result of a variety of factors including, among others, competition within the international oil and natural gas industry; long-term changes in the demand for crude oil, natural gas and refined products; the economic policies in the United States, China and the European Union; regulatory changes; changes in global supply, such as the current oversupply of crude oil; inventory levels; changes in the cost of capital; adverse economic conditions; global financial crises, such as the financial crisis of 2008; development of substitute sources of energy, development of new technologies; global and regional economic and political developments in the Organization of the Petroleum Exporting Countries, (OPEC); the willingness and ability of the OPEC and its members to set production levels; local and global demand and supply for crude oil, refined products and natural gas; trading activity in oil and natural gas, which thereby affects their respective margins; transactions in derivative financial instruments related to oil and gas; development or availability of alternative fuels; weather conditions; natural events or disasters; and terrorism and global conflict.

 

When crude oil, refined products and natural gas prices are low, we earn less revenue and we generate lower cash flow and less income. Conversely, when crude oil, refined product and natural gas prices are high, we earn more and generate a larger amount of cash and net income. During 2014, our crude oil basket price was US$87.3 per barrel versus US$43.9 per barrel in 2015; the refined product basket price was US$106.8 per barrel in 2014 versus US$63.4 per barrel in 2015; and the natural gas price was US$23.9 per barrel equivalent in 2014 versus US$22.1 per barrel equivalent in 2015.

 

In 2015, in connection with the current adverse economic context faced by the hydrocarbons sector, which resulted in a reduction in forecasted oil prices, lower expected refining margins in the coming years and an increase in market and country risk reflected in the discount rate, as well as a reduction in the recoverable reserves amount, among other factors, Ecopetrol recognized an impairment of non-current assets of COP$7,864,875 million before taxes. For additional information about this impairment loss, see Notes 14, 18, 19 and 29 to our consolidated financial statements.

 

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A reduction of international crude oil prices could also result in a delay or a change in our capital expenditure plan, in particular delaying exploration and development activities, thereby delaying the development of reserves and affecting future cash flows. In order to maintain a profitable operation and preserve the cash flow of the Company under current oil price levels, some of our producing fields may have to be closed or their operations temporarily suspended which would affect our production levels and expected revenues

 

Changes in the Colombian Peso/U.S. dollar exchange rate could have an adverse effect on our financial condition and results of operations given the amount of U.S. dollar denominated debt obtained by the company and the fact that most of our revenues is derived from sales of products quoted in or with reference to U.S. dollars.

 

Most of our revenues are derived from sales of products quoted in or with reference to U.S. dollars. Therefore when the Colombian Peso depreciates against the U.S. dollar, our revenues converted into Colombian Pesos, increase. Conversely, when the Colombian Peso appreciates against the U.S. dollar, our revenues decrease.

 

On the other hand, imported goods, oil services and the debt, which is mainly denominated in U.S. dollars, become less expensive when the Colombian Peso appreciates against the U.S. dollar and more expensive when the Colombian Peso depreciates against the U.S. dollar.

 

Thus, from a cash flow perspective, the impact on our operations of fluctuations in exchange rates, especially the Colombian Peso/U.S. dollar, has been and may continue to be material.

 

As of December 31, 2015 our U.S. dollar-denominated total debt was US$14.6 billion, which we recognize in our consolidated financial statements at its amortized cost, which corresponds to the present value of cash flows, discounted at the effective interest rate. Out of this total, US$11.1 billion relate to Ecopetrol S.A., whose functional currency is the Colombian Peso. Therefore, when the Colombian Peso depreciates against the U.S. dollar, the Company is exposed to an exchange rate loss. In contrast, when the Colombian Peso appreciates against the U.S. dollar, the Company has an exchange rate gain. Some of the group’s affiliates have the U.S. dollar as functional currency and are not exposed to exchange rate risk. On the asset side, when the financial statements of the Group are consolidated, the exchange rate differential of the affiliates whose functional currency is the U.S. dollar is recognized directly in the equity, as part of the other comprehensive income.

 

As of October 1, 2015, Ecopetrol S.A. adopted hedge accounting as part of its risk management strategy, using the natural hedge between exports and dollar-denominated debt. As such, 49% of Ecopetrol S.A’s debt in dollars was designated as hedge instrument of its future export sales for the period of 2015- 2023, see Note 4.1.4 to our consolidated financial statements for further explanation of the accounting policy and Note 31.2.1 for details of the hedge accounting adopted. With the adoption of hedge accounting, the effect of the volatility of the foreign exchange rate on the hedged portion of the debt is recognized directly in equity, as part of other comprehensive income. The remaining portion of Ecopetrol S.A.’s dollar-denominated debt continues exposed to the fluctuation of the exchange rate.

 

The U.S. dollar/Colombian Peso exchange rate has fluctuated during the last several years.  On average, the Colombian Peso depreciated 3.9% against the U.S. dollar in 2013, 7.1% in 2014 and 37.3% in 2015. Additionally, as of December 31, 2015 and December 31, 2014, the Colombian Peso depreciated 31.6% and 24.2%, respectively, from year-end exchange in the previous year.

 

A future depreciation in the exchange rate of the Colombian Peso against the U.S. dollar may affect our financial results when converted into Colombian Pesos, given the portion of our U.S. dollar debt that is not designated as hedge instrument and the future debt we may acquire. Please see our sensitivity analysis on our results of operation to exchange rate fluctuations in the section Financial Review—Effect of Taxes, Exchange Rate Variation, Inflation and the Price of Oil on our Results—Exchange Rate Variation and in Note 31.2.2 to our consolidated financial statements.

 

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Increased competition from local and foreign crude oil companies may have a negative impact on our ability to gain access to additional crude oil and natural gas reserves in Colombia and abroad .

 

We must bid for exploration blocks offered by the ANH (see a description of ANH in Section 3.8.1. Principal Regulatory Bodies) in Colombia and by similar authorities in other countries, which means we compete under the same conditions as other domestic and foreign oil and gas companies, and receive no special treatment. Our ability to obtain access to potential production fields also depends on our ability to evaluate and select potential hydrocarbon-producing fields and to adequately bid for these exploration fields.

 

We are also exposed to international competition as a result of our international exploratory activities. Currently, we are developing exploratory activities in Brazil, Peru and the Gulf of Mexico, where we face competition from other oil and gas companies operating in those locations.

 

If we are unable to adequately compete with local and foreign oil companies, or if we cannot enter into joint ventures with market players with exploration projects where we could potentially find additional reserves, our exploration activities may be limited. This could reduce our share of the market and, in turn, adversely affect our financial condition.

 

If operational risks to which we are exposed in Colombia or overseas materialize, the health and safety of our workforce, the local community and the environment may be affected. In addition, we may suffer a disruption or shutdown of our operational activities.

 

Our exploration, production, refining and transportation activities in Colombia and in the foreign countries in which we operate are subject to industry-specific operating risks, some of which, despite our internal procedures and adherence to industry best practices, are beyond our control. Our operations may be curtailed, delayed or cancelled due to adverse or abnormal weather conditions, natural disasters, blockages in the communities in which we operate, equipment failures or accidents, oil or natural gas spills or leaks, shortages or delays in the availability or in the delivery of equipment, delays or cancellation of environmental licenses or other government authorizations or judicial decisions, fires, explosions, blow-outs, surface cratering, pipeline failures, theft and damage to our transportation infrastructure, sabotage, terrorist attacks and criminal activities.

 

Some of our operations in Colombia and abroad could be conducted in remote and uninhabited locations which involve health and safety risks that could affect our workforce. By our own Company policy and practices, as well as under Colombian law and international industrial safety regulations, we are required to have health and safety practices that minimize risks and health issues faced by our workforce. Failure to comply with health and safety regulations in the jurisdictions where we operate may lead to investigations by health officials that could result in lawsuits or fines.

 

We may be required to incur additional costs and expenses to allocate funds to industrial safety and health compliance under Colombian law and international industrial safety regulations. Additionally, if any operational incident occurs that affects local communities and ethnic communities in nearby areas, we will need to incur additional costs and expenses in order to return affected areas to normality and to compensate for any damages we may cause. These additional costs may have a negative impact on the profitability of the projects we may decide to undertake.

 

The occurrence of any of these operating risks could result in substantial losses or slowdowns to our operations, including injury to our employees, malfunction or destruction of property, equipment and infrastructure, clean-up responsibilities, third-party liability claims, government investigations and imposition of fines, withdrawal of environmental licenses and other government permits, suspension or shutdown of our activities and loss of revenue. The occurrence of any of these events may have a material adverse effect on our financial condition and results of operations.

 

Our involvement in deep water drilling either as direct operators or in conjunction with our business partners involves risks and costs, which may be outside of our control.

 

Our deepwater drilling activities present severe risks, such as the risk of spills, explosions in platforms and drilling operations, and natural disasters. The occurrence of any of these events or other incidents could result in personal injuries, loss of life, severe environmental damage with the resulting containment, clean-up and repair expenses, equipment damage and liability in civil and administrative proceedings. Heightened risks and costs associated with deep water drilling may have a negative effect on our results of operations, financial condition and reputation. See the section Business Overview—Exploration and Production—Exploration Activities—Exploration Activities Outside of Colombia for a summary of our current deepwater drilling activities.

 

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As a result of the oil spill in the Macondo field operated by British Petroleum in the U.S. Gulf Coast in April 2010, significant concerns regarding the safety of deep water drilling have been raised and, as a result, applicable regulations in various countries have changed. More stringent government regulation may result in increased costs and longer exploration and development timeframes for our deep water drilling operations and consequently could adversely affect our results of operations and financial condition.

 

The takeover of fields following the termination of association contracts may impact our production and performance.

 

The takeover of fields following the expiration of an association contract involves risks that may hinder the continuity of the development of those fields. The main risks in executing a takeover are: not accomplishing our production targets, managing the expectations of the communities in surrounding areas, preserving ownership of the required land rights following the takeover, discovering previously unidentified environmental liabilities and securing any remaining payments subsequent to the date of termination, among others. Failure to achieve a precise transition between operators may therefore have a negative impact on our results of operation and financial condition.

 

The Rubiales risk participation and Piriri joint venture contracts, in which we currently have a 60% and 50% interest, respectively, will expire on June 30, 2016. Given that these two contracts represented 12% of the total production of Ecopetrol in 2015, if we are unable to successfully secure the takeover of these contracts our overall results of operations may be negatively affected.

 

We are exposed to the credit, political and regulatory risks of our customers and any material nonpayment or nonperformance by our key customers could adversely affect our cash flow and results of operations.

 

Some of our customers may experience financial problems that could have a significant negative effect on their creditworthiness. Severe financial problems encountered by our customers could limit our ability to collect amounts owed to us, or to enforce the performance of obligations owed to us under contractual arrangements. In addition, many of our customers finance their activities through their cash flows from operations, short and long term debt or equity.

 

The combination of decreasing cash flows as a result of declines in commodity prices, a reduction in borrowing bases under reserve-based credit facilities and the lack of availability of debt or equity may result in a significant reduction of our customers’ liquidity and limit their ability to make payments or perform their obligations to us.

 

Furthermore, some of our customers may be highly leveraged and subject to their own operating expenses. Therefore, the risk we face in doing business with these customers may increase. Other customers may also be subject to regulatory changes, which could increase the risk of defaulting on their obligations to us. Financial problems experienced by our customers could result in the impairment of our assets, a decrease in our operating cash flows and may also reduce or curtail our customers’ future use of our products and services, which may have an adverse effect on our revenues and our ability to make payments under our existing debt obligations.

 

Our ability to access the credit and capital markets on favorable terms to obtain funding for our capital projects may be limited due to the deterioration of these markets, any change to our credit ratings and the authorizations we need before incurring any financial indebtedness.

 

We expect to make significant capital and operations expenditures to reach our corporate goals. Our ability to fund these expenditures is dependent on our ability to generate revenue, or access the capital necessary to finance them on terms acceptable to us. In recent years, particularly during the last quarter of 2015 and then first quarter of 2016, due to significant decrease in oil prices, domestic and global financial markets and economic conditions have been weak and volatile and have contributed significantly to a substantial deterioration in the credit and capital markets. A new financial crisis, further decline in prices in the oil and gas sector, continued slowdown of China’s economy, which in turn could worsen the risk perception with respect to the emerging markets, or the occurrence of any of the risks described in the section Risk Review—Risk Factors—Risks Related to Colombia’s Political and Regional Environment could also make it more difficult for us and our subsidiaries to access international and local capital markets and finance our operations and capital expenditures in the future on terms acceptable to us. These conditions, along with significant write-offs in the financial services sector and the re-pricing of credit risk, can make it difficult for us to obtain funding for our capital needs on favorable terms. Access to credit and capital markets is also dependent on our credit ratings, which are mainly determined by our financial and operational strength, oil and gas market conditions and the support that could be provided by the Colombian government. On January 18, 2016, our senior unsecured debt ratings were downgraded to Baa3 from Baa2 by Moody’s Investors Service.  We cannot assure that our credit ratings will continue for any given period of time or that the ratings will not be further lowered or withdrawn.  An assigned rating may be raised or lowered depending, among other things, on the respective rating agency’s assessment of our financial strength. In addition, a downgrade in the rating of the Republic of Colombia could also trigger a downgrade on our ratings as our rating is capped by the rating of the Republic of Colombia and the implicit support that can potentially be provided to the Company. On February 16, 2016, S&P revised the outlook of the Republic of Colombia to negative.

 

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As a result of these factors, we may be forced to revise the timing and scope of our capital projects as necessary to adapt to existing market and economic conditions, downgrades to our credit ratings or to access the financial markets on terms less favorable, therefore negatively affecting our results of operations and financial condition.

 

In addition, under applicable regulation, the Government, through the Ministry of Finance and Public Credit and the favorable opinion of the National Planning Department, must authorize all indebtedness of state-owned entities and government-controlled companies through a majority equity stake. Consequently, all of our indebtedness, except for our foreign subsidiaries or those subsidiaries in which we hold minority interest, must be previously authorized by the Colombian Ministry of Finance and Public Credit and the National Planning Department. As such, our indebtedness is subject to the Government’s time frames and policies, and we cannot guarantee that such authorizations would be granted in a timely fashion or granted at all.

 

We may be exposed to increases in interest rates, thereby increasing our financial costs.

 

We may incur debt locally and in the international capital markets and, consequently, may be affected by changes in prevailing interest rates. If market interest rates increase, our financing expenses may increase, which could have an adverse effect on our results of operations and financial condition.

 

As of December 31, 2015, approximately 30.1%, or US$4.9 billion, of our total long term indebtedness consisted of floating rate debt. If market interest rates rise, our financing expenses will increase, which could have an adverse effect on our results of operations and financial condition. In addition, as we refinance our existing debt in the coming years, the mix of our indebtedness may change, specifically as it relates to the ratio of fixed to floating interest rates, the ratio of short-term to long-term debt, and the currencies in which our debt is denominated in or indexed to. We cannot assure you that such changes will not result in increased financing expenses borne by us. Finally, as we incur new debt in the future to fund our capital projects, the prevailing interest rates and spreads at any specific time could be less favorable in terms of cost when compared to our previous financing transactions, which could adversely affect our financial condition and results of operations.

 

Our current and planned investments and exploration activities outside Colombia are exposed to political and economic risks.

 

As part of our Strategic Plan, we operate through business partners, subsidiaries or affiliates outside of Colombia. We currently have investments and subsidiaries incorporated in Peru, Brazil, Bermuda, Panama, the Cayman Islands, Switzerland, Germany, Spain, the United Kingdom and the United States, and we are analyzing investments in other countries. In connection with making investments, we are and will be subject to risks related to economic and political conditions and governmental economic actions. We cannot predict the positions of foreign governments relating to the oil and gas industry, land tenure, protection of private property, environmental standards, regulation or taxation; nor can we assure you that future governments will maintain policies favorable to foreign investment or repatriation of capital.

 

We began exploration activities outside Colombia in 2006 through our Brazilian subsidiary, Ecopetrol Óleo e Gás do Brasil Ltda. Our foreign subsidiaries have subsequently entered into a number of joint venture exploration agreements with regional and international oil companies to explore blocks in Peru, Angola, Brazil and the U.S. Gulf Coast. We have limited experience exploring outside Colombia. We may face new and unexpected risks involving environmental and other legal requirements beyond those we currently face.

 

The results of operations and financial condition of our subsidiaries in these countries also may be adversely affected not only by risks associated with hydrocarbon exploration and production, but also by fluctuations in their local economies, political instability and government actions, including: the imposition of price controls, the imposition of restrictions on hydrocarbon exports, fluctuation of local currencies against the Colombian Peso, the nationalization of oil and gas reserves, increases in export tax and income tax rates for crude oil and oil products, and unilateral (governmental) institutional and contractual changes, including controls on investments and limitations on new projects.

 

Any of these conditions occurring could disrupt or terminate our operations, causing our development activities to be curtailed or terminated in these areas, or our production to decline; limit our ability to pursue new opportunities; affect the recoverability of our assets; or cause us to incur additional costs or delay the timeline of our projects.

 

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Our future performance depends on the successful development and deployment of new technologies and the knowledge to apply and improve them.

 

Technology, knowledge and innovation are essential to our business, especially for improvements in the production and transportation of heavy crude oil, the exploitation of mature fields, and reductions in our operating cost. If we do not develop the right technology or do not obtain the expertise to operate new technology or to improve our processes, do not have access to, or do not deploy the knowledge necessary to apply and improve such technology effectively, the execution of our corporate goals, our profitability and our earnings may be adversely affected.

 

Our performance could be negatively affected by a deficiency in leadership capacity and lack of key skilled employees.

 

As the oil and gas industry faces an increasing number of challenges, the ability to react quickly to these challenges has become a key factor in achieving efficiency, profitability and sustainability. Our ability to achieve these goals can be negatively affected by a deficiency in leadership capacity and a lack of key skilled employees that can execute our business strategy with creativity and determination.

 

Our operations may not be able to keep pace with the increasing domestic demand for natural gas.

 

According to the Colombian Energy and Gas Regulatory Commission (CREG) Resolution 089 of 2013, a supplier of natural gas must possess sufficient economically viable natural gas reserves before executing a natural gas delivery contract with a customer. In the long term, we may not be able to keep up with increasing local demand for natural gas if demand outpaces the rate of growth of our natural gas supply, especially because of the decline of our main fields. As a result, we may lose market share, which may negatively impact our financial condition and results of operations.

 

Additionally, we are currently party to a number of national gas supply contracts that have firm gas commitments. If we are unable to deliver natural gas to these clients as a result of cuts in operations, delays in the completion of projects relating to our production facilities or the acceleration of the decline in our gas production, among other reasons, we may be required to compensate our customers for our failure to supply natural gas.

 

Delays in the start of new projects could result in penalties imposed on us by our clients. Although we did not pay any such penalties in 2015, we cannot assure you that in the future we will not be subject to additional monetary fines which can in turn affect our financial condition and results of operations.

 

We depend on others for the construction and availability of natural gas transportation infrastructure for the transport of our gas, which may limit our ability to develop new or existing fields or lead to the deterioration of related assets and may not allow us to recover the cost of capital invested in natural gas discoveries.

 

We are prohibited by law from holding more than 25% of the equity of any natural gas transportation company. Therefore, there can be no assurance that the transportation infrastructure necessary to transport natural gas from the fields to distribution points and our customers will be built by third parties or that if built there will be sufficient capacity available to us for the exploitation of new natural gas discoveries or the development of existing fields. The failure to commercially exploit new or existing discoveries may result in impairment of the related assets and our inability to recover the capital expenditures invested to make these natural gas discoveries. As a result, we may be required to enter into agreements with natural gas transportation companies on terms that are not favorable to us.

 

For example, we have developed natural gas reserves in the Cusiana and Cupiagua fields, but transportation capacity to deliver gas from these fields is currently limited.

 

Our operations have and may continue to be affected by reactions of labor unions, social organizations and contractors to organizational changes and other management decisions.

 

Due to the volatility of the markets and the existing low oil price environment, we have and will continue to undertake measures to enhance operating cost efficiency. Such measures involve changes in cost structure, downsizing our staff (including direct and indirect employees), budget cuts, among others. Unions, contractors and social organizations in the communities where we have operations have in the past and may continue to oppose such measures causing work stoppages or decreasing productivity, which could have an adverse effect on our operations and financial condition.

 

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In addition, our current collective bargaining agreement has been in effect since 2014 and has a term of five years, expiring June 30, 2018. There will be no changes to these terms until 2018; therefore, we do not expect any adverse reactions from our labor unions relating to this matter. However, we cannot assure you we will not experience strikes or labor unrest in the future.

 

Our activities may be interrupted or affected by external factors, such as abnormal weather conditions and natural disasters.

 

We are exposed to several risks that may partially interrupt our activities. They include fires or explosions, natural disasters, criminal acts and acts of terror, malfunction of pipelines and emission of toxic substances.

 

Also, the effects of climate change could create impacts and losses in any part of our business operations, for instance, as the result of increase in the intensity of the “La Niña” and “El Niño” climate phenomena, causing floods and drought periods, increased temperature and rising sea levels.

 

The “El Niño” climate phenomenon is characterized by (i) a lack of rainfall, which limits the amount of water necessary for the development of various activities of the company, and (ii) increased temperatures, which could have a direct impact on our workers’ health given an increased occurrence of heat waves and the increased occurrence of epidemics and diseases. The “La Niña” climate phenomenon is characterized by increased rainfall, which can generate (i) landslides that threaten pipeline infrastructure and limit road transportation and (ii) flooding, which could limit operations in our production fields and facilities.

 

As a result, our activities could be significantly affected or even paralyzed. These risks could result in property damage, loss of revenue, loss of life, pollution and harm to the environment, among others. If any of these occur, we may be exposed to economic sanctions, damages, fines or penalties in addition to the costs required to repair or remediate the related damage. These costs, fines and penalties may adversely affect our financial condition and results of operations.

 

Our operations, including our activities in areas classified as indigenous reserves and Afro-Colombian lands, are subject to opposition from members of various communities.

 

We currently carry out and plan to carry out activities in areas classified by the Government as indigenous reserves (resguardos) and Afro-Colombian lands (territorios colectivos). In order to undertake these activities, we must first comply with the previous consultancy process, set forth by Colombian law. These consultation processes are part of the administrative procedures for obtaining environmental licenses to start our projects, works or activities in areas belonging to ethnic communities. Generally, these consultation processes last between four to six months, but may be significantly delayed if we cannot reach an agreement with the communities. We strive to be respectful of the Constitution and laws and the autonomy of indigenous and Afro-descendant communities, and we therefore do not enter their territories until we have reached an agreement with them.

 

Our activities are subject to opposition, including protests by various communities, and even in areas in which the previous consultancy process does not apply.

 

No assurance can be given that we will be able to reach an agreement with the different communities opposed to our operations or that such communities will participate in consultancy processes if available. We may be exposed to similar delays due to opposition from local communities in other countries where we carry out our activities.

 

We have made significant investments in acquisitions and we may not realize the expected value.

 

We have acquired interests in several companies in Colombia and abroad. See the section Business Overview—Our Corporate Structure. Obtaining the expected benefits of the acquisitions will depend, in part, on our ability to (i) obtain the expected operational and financial results from these acquisitions, (ii) manage disparate operations and integrate distinct corporate cultures, (iii) manage our objectives as a corporate group, and (iv) institute our corporate governance rules as well as other factors beyond our control such as (v) the economic and regulatory environment in countries in which we have made acquisitions and (vi) crude oil prices. These efforts may not succeed. Our failure to successfully obtain the expected results from our acquisitions could adversely affect our financial condition and results of operations.

 

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Our construction of large projects, such as those being undertaken by our subsidiaries Reficar, Bioenergy S.A. and Bioenergy Zona Franca S.A.S., may be delayed or cost more than projected, which could affect our operating results and financial condition.

 

Our current and future investment projects could face planning and implementation problems, which could impact the cost and profitability of our programs and projects, adversely affecting our results of operation and financial condition.

 

For example, Reficar raised US$3.5 billion through a limited-recourse project financing in which we provided both a construction support and a debt service guarantee. If the construction of the project to upgrade the Cartagena Refinery is delayed because of operational problems, Ecopetrol S.A. must provide the sufficient financial resources, either by means of capital contributions or by granting a subordinated loan, until Reficar reaches project completion. Operational problems may include, but are not limited to, labor productivity or unavailability of construction material in the development of the project, or failure of the upgraded refinery to reach the expected performance level in terms of the quality of products and/or volumes produced. If Ecopetrol S.A. is required to provide additional capital or guarantees, other strategic projects may be delayed or cancelled, thereby affecting our operating results and financial condition.

 

In 2013, 2014 and 2015, we were called upon to provide Reficar with financial support beyond the US$3.5 billion Reficar raised through limited-recourse project financing. Reficar has requested the following amounts under the Construction Support Agreement, approximately US$1.0 billion, US$1.4 billion and US$722 million in 2013, 2014 and 2015, respectively, for the construction of the project. Any increase in the project’s capital expenditures is expected to be funded under the Construction Support Agreement between Reficar and Ecopetrol S.A. See the section Business Overview—Refining and Petrochemicals—Refining—Reficar.

 

Ecopetrol S.A. also provided Reficar with a liquidity mechanism by means of the Debt Service Guarantee Agreement, in order to allow Reficar to pay its debt service in situations in which there are liquidity shortfalls, as well as establishing a mechanism pursuant to which Reficar can exit the project finance by transferring its debt to Ecopetrol S.A. During 2015 and 2014, the requested amounts by Reficar under the Debt Service Guarantee Agreement were US$378 million and US$241 million, respectively. 

 

Any further delays in the implementation of the project may result in larger capital expenditures, which could increase the overall cost of the project and impact our financial results.

 

Bioenergy S.A and Bioenergy Zona Franca S.A.S. are executing the construction of an ethanol plant with an installed capacity of 480,000 liters per day. The project is currently expected to begin commercial operations by the end of 2016. Any performance defaults, social unrest, strikes or other labor actions strikes could negatively impact this estimated date, costs of the project and our financial results.

 

Our results may be affected by the performance of our business partners or their third-party service providers, as many of our operations are executed under joint venture agreements with business partners.

 

Many of our operations are performed through joint ventures with our business partners. Consequently, we depend on the performance of our business partners. The poor performance of any of our business partners, especially in those projects in which we do not act as operator, could negatively impact oil and natural gas production, which in turn could have a negative impact on our results of operations and financial condition. We are exposed to the risk of not finding business partners with the appropriate skills and performance we require for our projects. We are also indirectly exposed to supply agreements and other third-party services contracted by our business partners acting as operators under joint venture agreements.

 

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Our insurance policies do not cover all liabilities and may not be available for all risks.

 

Our insurance policies do not cover all liabilities, and insurance may not be available for all risks. There can be no assurance that incidents will not occur in the future, that insurance will adequately cover the entire scope or extent of our losses or that we will not be found liable in connection with claims arising from these and other events, which could adversely affect our financial condition and results of operations.

 

A failure in our information technology systems or cyber security attacks may adversely affect our financial results.

 

We depend on the reliability and security of our information technology systems to conduct certain exploration, development and production activities, process financial records and operating data, communication with our employees and business partners, and for many other activities related to our business. Our information technology systems may fail or have other significant shortcomings due to operational system flaws or employee misuse, tampering or manipulation. In addition, we may become the target of cyber-attacks or information security breaches that could result in the unauthorized release, gathering, monitoring, misuse, loss or destruction of proprietary and other information. Any of these occurrences could disrupt our business, result in potential liability or reputational damage or otherwise have an adverse effect on our financial results.

 

During 2015, our internal cyber security systems identified 92,503 Command & Control attacks designed to extract information from Ecopetrol S.A. Our platforms also identified and controlled certain Advanced Persistent Threats aimed at company personnel through emails, including through (i) phishing, spam, spyware/greyware and malware events; (ii) Botnets, Malnets and dangerous websites connections; and (iii) a DDoS attack.

 

Although we have not experienced any material losses relating to failure of our information technology systems or cyber incidents, there can be no assurance that we will not suffer such losses in the future.

 

We are exposed to behaviors incompatible with our ethics and compliance standards.

 

Given the large number of contracts that we are a party to in Colombia and abroad with local and foreign suppliers, the geographic distribution of our operations and the great variety of actors that we interact within the course of business, we are subject to the risk that our employees, contractors, or any person having relations with us may misappropriate our assets, manipulate our assets or information or engage in money laundering or the financing of terrorism, for such person’s personal or business advantage. Our systems for identifying and monitoring these risks may not be effective to fully mitigate them in all situations. Such acts may result in material financial losses or reputational harm to the Company.

 

Unavailability of electric power may affect or limit the continuity of our operations or growth.

 

Ecopetrol S.A.’s average energy consumption in 2015 was 6,740,512 MWh/year equivalent, of which 91% was supplied through self-generation, and the remaining 9% through unregulated purchases of electrical energy in the open market. Given our expected production levels and the start of a new transport and refining system, it is possible that during the next few years there will be insufficient electrical energy for our operations or the operations of fields in which we are a non-operating partner. This is because of the unavailability of market power given the delay of several energy transmission and generation infrastructure projects, the increase in the share of consumption by non-regulated users, and because of high dependency on the execution of self-generation and transmission projects and contracts managed by us or by our business partners that are exposed to a number of risks, including high volatility in national energy conditions (such as hydrology, availability of natural gas), licensing restrictions and attacks on infrastructure, among others.

 

Rising water production levels may affect or constrain our crude oil production.

 

During 2015, Ecopetrol S.A. produced approximately 10.8 million barrels of water per day. Taking into account the nature of our reservoirs, the water production levels to be managed by the Company may increase in the future. In order to achieve our oil and gas production goals and to avoid any production restrictions going forward, we will need to secure the required capacity to manage water levels. Factors that may trigger a possible constraint in our crude oil production due to the rising water production levels are: (i) ineffective project management of the required facilities, (ii) the Company’s and its partners’ ability to timely obtain the environmental permits related to water management, (iii) social and community interactions that could affect the development and operation of these projects, and (iv) the availability of capital to execute the required projects.

 

 

5.1.2Risks Related to Colombia’s Political and Regional Environment

 

This section discusses potential risks related to our extensive operations in Colombia.

 

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The Colombian government could seize or expropriate Ecopetrol’s assets under certain circumstances.

 

Pursuant to Article 58 and 59 of the Colombian constitution, the Government can exercise its eminent domain powers in respect of Ecopetrol’s assets in the event such action is deemed by the Government to be required in order to protect public interests. According to Law 388 of 1997, eminent domain powers may be exercised through: (i) an ordinary expropriation proceeding (expropiación ordinaria o judicial), or (ii) an administrative expropriation (expropiación administrativa). In all cases we would be entitled to a fair compensation for the expropriated assets. Also, as a general rule, compensation must be paid before the asset is effectively expropriated. However, the compensation may be lower than the price for which the expropriated asset could be sold in a free-market sale or the value of the asset as part of an ongoing business. Additionally, Article 59 of the Colombian constitution establishes an expropriation for war reasons (expropiación en caso de guerra), which does not that compensation be paid before expropriation but can only be executed on a temporary basis.

 

Colombia has experienced internal security issues that have had or could have a negative effect on the Colombian economy and on us.

 

Colombia has experienced internal security issues, primarily due to the activities of guerrillas, paramilitary groups, drug cartels and criminal bands known as Bacrim. From time to time, guerrillas target crude oil and multi-purpose pipelines, including the Oleoducto Transandino, Caño Limón-Coveñas and Oleoducto Bicentenario pipelines, and other related infrastructure disrupting our activities and those of our business partners. During 2015, the attacks against our pipeline infrastructure decreased by 38% in relation to 2014 (130 attacks in 2014 compared with 80 attacks in 2015), however they were strategically targeted and more severe. This situation especially affected the infrastructure located in Putumayo, Nariño, Arauca and Norte de Santander and the following pipelines: Caño Limón Coveñas, Transandino and San Miguel Orito. On several occasions, guerilla attacks have resulted in unscheduled shutdowns of transportation systems in order to repair or replace sections of pipelines or production facilities that have been damaged and deferral of production in certain fields, as well as caused us to undertake environmental remediation. For the pipeline infrastructure managed by Ecopetrol S.A., the direct cost of repair pipeline infrastructure due to terrorist attacks in 2015 was approximately COP$56.5 billion (US$18 million, with a 3,149.47 Colombian Peso/U.S. dollar exchange rate as of December 31, 2015). Also, our production was impacted by approximately 6,800 bpd due to events related to attacks on our infrastructure that limited our production. Guerrilla groups and other illegal armed groups also attacked natural gas transportation infrastructure that have affected our natural gas production in the past. These activities, their possible escalation and the effects associated with them have had, and may have in the future, a negative impact on the Colombian economy or on us, which may affect our customers, employees, assets or the environment, with resulting containment, clean-up and repair expenses.

 

Likewise, theft of refined products and crude oil, resulting from security issues, may impact our results in the future. Theft of refined products, which reached a peak of approximately 7,270 bpd in 2002, was reduced to around 44 bpd in 2014 and to approximately 30 bpd in 2015. The theft of crude oil decreased from approximately 835 bpd in 2014 to approximately 646 bpd in 2015.

 

Peace negotiations between the Colombian government and the guerrilla groups may not be fruitful

 

Since 2012, the Colombian government has been in negotiations with the Revolutionary Armed Forces of Colombia, or FARC, the largest guerrilla group in Colombia, with a view to end the armed conflict. This is the latest attempt in a series of unsuccessful negotiations between the Colombian government and the FARC. While the process is ongoing, military operations and hostilities continue. If the negotiations fail, the intensity of the internal armed conflict could increase, resulting in a deterioration of Colombia’s national security and, consequently, negatively impacting our operating results. However, even if the negotiations turn out to be successful, some of the guerrilla groups may continue their illegal and terrorist activities, which could affect our operations.

 

The Colombian government and the country’s largest guerrilla group have made a joint request to the United Nations Security Council and are nearing the final stages of an armistice negotiation. The two sides have asked the United Nations Security Council to set up a mission of international experts to oversee a critical part of the proposed agreement: disarming the FARC.

 

The Colombian government envisions that the FARC will assemble its fighters in a handful of regions once a final peace agreement is signed and that fighters will start to gradually transition into civilian life. However, FARC rebels explicitly backed out of the agreement, claiming that the Colombian government has stalled the process.

 

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On the other hand, the National Liberation Army, or ELN, an insurgency guerrilla group, has increased its actions against the Colombian security forces and the critical infrastructure of the Nation in recent months, which we believe is an attempt to show its presence and influence in some regions and put pressure on the peace negotiations process that the ELN and the Colombian government started on March 30, 2016. In addition, the possibility of a peace agreement with the ELN is uncertain due to internal division among its leaders.

 

There have been certain events in Colombia and abroad, which have resulted in political tensions between Colombia and some of its neighboring countries.

 

Diplomatic relations between Colombia and some of its neighboring countries, in particular Ecuador and Venezuela, have been tense in the past. These political tensions were heightened by the Colombian government’s allegations that neighboring countries were supporting the guerilla groups, as well as by claims made by Venezuela stating that the Colombian army has entered its territory while in pursuit of FARC members. Although relations with these countries have stabilized, there can be no assurance that similar allegations that may result in new and heightened tensions with Colombia’s neighbors would not be made again as was done in the past, and would not have a negative impact on Colombia’s economy and general security situation.

 

Companies operating in Colombia, including us, are subject to the prevailing economic conditions and the investment climate in Colombia, which may be less stable than the prevailing economic conditions and investment climate in developed countries.

 

Market prices of securities issued by Colombian companies, including us, are subject to the prevailing economic conditions in Colombia. A large portion of our assets and operations are located in Colombia and most of our sales are currently derived from our crude oil and natural gas production and the production of our refineries located in Colombia. Accordingly, our financial condition and results of operations depend to a significant extent on macroeconomic and political conditions prevailing from time to time in Colombia and on the exchange rates between the Colombian Peso and the U.S. dollar.

 

If the perception of improved overall security in Colombia deteriorates or if the investment climate worsens, the Colombian economy may face lower growth rates than the ones posted recently, which could negatively affect our financial condition and results of operations. Furthermore, the market price of our shares and American Depositary Shares, or ADSs, may be adversely affected by changes in governmental policies, particularly those affecting economic growth, exchange rates, interest rates, inflation and taxes. The Government has changed monetary, fiscal, taxation, labor and other policies over time and has thus influenced the performance of the Colombian economy. We have no control over the extent and timing of government intervention and policies.

 

Colombian political and economic conditions have a direct impact on our business and may have a material adverse effect on us.

 

Colombia’s economic policies may have direct impact on our company as well as market conditions, the prices of securities and our ability to access national and international capital markets. Our financial condition and results of operations may be adversely affected by the following factors, among others, and the Government’s response to such factors: exchange rate movements; inflation; exchange control policies; price instability; interest rates; liquidity of domestic capital and lending markets; tax policy; regulatory policy for the oil and gas industry, including pricing policy; and other political, diplomatic, social and economic developments in or affecting Colombia.

 

Uncertainty over whether the Government will implement changes in policy or regulations that may affect any of the factors mentioned above or other factors in the future may lead to economic uncertainty in Colombia and increase the volatility of the Colombian securities market and securities issued abroad by Colombian companies.

 

Developments and the perception of risk in other countries, especially emerging market countries, may adversely affect the market price of Colombian securities, including our ADSs.

 

Securities issued by Colombian companies may be affected by economic and market conditions in other countries, including other Latin American and emerging market countries. Although economic conditions in Latin American countries and in other emerging market countries may differ significantly from economic conditions in Colombia, investors’ reactions to developments in these other countries may have an adverse effect on the market value of securities of Colombian issuers and our ability to access capital markets.

 

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Due to past financial crises in several emerging market countries (such as the Asian financial crisis of 1997, the Russian financial crisis of 1998 and the Argentine financial crisis of 2001), the world financial crisis of 2008 and the recent sovereign debt crises in certain European countries, investors may view investments in emerging markets with heightened caution. In the past, as a result of crises in other countries, flows of investments into Colombia have been reduced. Crises in other countries, especially in emerging market countries, may hamper investor enthusiasm for securities of Colombian issuers. If Latin America experiences a new slow-down or if the price for securities of Latin American issuers falls, the price for our ADSs could follow this trend and could be adversely affected as could our ability to access domestic or international capital markets.

 

The Ministry of Mines and Energy has not calculated or liquidated the Net Position for each refiner and/or importer and for each fuel (gasoline and motor fuel oil) to be recognized by the FEPC to Ecopetrol

 

Under current Colombian regulations, the Ministry of Mines and Energy is required to calculate and liquidate each refiner and/or importer of fuel’s Participation Differential (i.e. this arise when the international parity price is lower than the reference price established by the Ministry of Mines and Energy, leading to a “Net Position” every six months to be paid by the FEPC). However, the Ministry of Mines and Energy has not calculated or liquidated the Net Position for each refiner and/or importer and for each fuel (gasoline and diesel) to be paid by the FEPC to Ecopetrol since the third quarter of 2014. We do not know and we cannot anticipate the terms and conditions that will be established by the Ministry of Mines and Energy for future liquidations after the Court´s decision included in the sentence C-726 of November 25, 2015. For more information regarding the FEPC, see the section Business Overview—Applicable Laws and Regulations—Regulation of Refining and Petrochemical Activities—Regulation Concerning Production and Prices.

 

New or higher taxes resulting from changes in tax regulations or the interpretation thereof in Colombia could adversely affect our results of operations and financial condition.

 

New tax laws and regulations, and uncertainties in the interpretation with respect to existing and future tax policies pose risks to us. In recent years, the Colombian Congress and tax authorities have imposed additional taxes such as the Impuesto sobre la Renta para la Equidad (“CREE surtax”), and enacted modifications to taxes related to financial transactions, income, value added tax (“VAT”), and taxes on net worth. For a description of taxes affecting our results of operations and financial condition in 2015, see the section Financial ReviewEffect of Taxes, Exchange Rate Variation, Inflation and the Price of Oil on Our ResultsTaxes. Changes in tax-related laws and regulations, and interpretations thereof, can affect tax burdens by increasing tax rates and fees, creating new taxes, limiting tax deductions, and eliminating tax-based incentives and non-taxed income. In addition, tax authorities and tax courts may interpret tax regulations differently than we do, which could result in tax litigation and associated costs and penalties. For Colombian income tax purposes and, as a general rule, dividends that are distributed from profits taxed at the corporate level are not taxed or subject to withholding tax at the shareholder level. Tax treaty rules might also apply on dividend distributions when a shareholder is a resident in a country that has executed a tax treaty with Colombia. However, the tax treatment currently applicable to dividends that are distributed from profits may change in the future, and any change could have an adverse effect on our financial condition and the taxable burden applicable to us as shareholders.

 

Currently, there is not a bill pending in Congress relating to tax matters. However, the Colombian government convened a committee of experts (the “Committee of Experts”) to analyze the current Colombian tax system and to propose changes to such system. Although the final report drafted by the Committee of Experts is neither mandatory nor binding, the Colombian government has announced that it plans to submit to Congress a structural tax reform in 2016 based on the final report.

 

The key proposed reforms in the final report are the following:

 

·To replace the current structure of taxation on profits (including income tax, CREE tax and CREE surtax) with a single Corporate Profit Tax (IUE, for its acronym in Spanish). The IUE rate is proposed to be between 30% and 35% and the taxable base of the IUE will be based on total profit calculated in accordance with IFRS.

 

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·To eliminate the wealth tax (net worth tax), special tax deductions and tax discounts, and certain tax benefits.

 

·To tax dividends at the shareholder level, in cases where the shareholder is a person or a foreign entity.

 

·To increase the presumptive income tax rate from 3% to 4% of the taxpayer’s net equity for the prior year.

 

·To increase the VAT tax rate from 16% to 19%.

 

The Colombian government has stated that no tax bill will be submitted to Congress during the first half of 2016. However, it is expected that a tax bill will be submitted by the Colombian government and enacted by Congress during the second half of 2016. Therefore, the tax reform is expected to be effective in 2017 for taxes and withholdings accrued on annual basis. However, as of the date of this annual report, we cannot offer any assurance as to when and if the tax reform would be submitted and whether it would be passed as drafted by the Committee of Experts.

 

5.1.3Legal and Regulatory Risks

 

This section discusses potential legal and regulatory risks to Ecopetrol, including the risk of having to comply with new laws and regulations.

 

Our operations are subject to extensive regulation.

 

The Colombian hydrocarbons industry is subject to extensive regulation and supervision by the Government and regulatory agencies in matters including the award of exploration and production blocks by the ANH, the imposition of specific drilling and exploration obligations, restrictions on production, price controls, capital expenditures and required divestments. Existing regulation applies to virtually all aspects of our operations in Colombia and abroad. The commercialization activities of some of our products also face extensive regulation. Such regulation is subject to change by the applicable regulator affecting our ability to commercialize our products. See the section Business Overview—Applicable Laws and Regulations.

 

The terms and conditions of the agreements with the ANH under which we explore and produce crude oil and natural gas generally reflect negotiations with the ANH and other governmental authorities and may vary by fields, basins and hydrocarbons discovered.

 

We are required, as are all oil companies undertaking exploratory and production activities in Colombia, to pay a percentage of our production to the Government as royalties. The Colombian Congress has modified the royalty program for crude oil and natural gas production several times in the last 20 years, as it has modified the regime regulating new contracts entered into with the Government. In the future, the Colombian Congress may once again amend royalty payment levels for new contracts and such changes could have an adverse effect on our future exploration and production in Colombia. See the section Business Overview—Applicable Laws and Regulations—Regulation of Exploration and Production Activities—Business Regulation—Royalties for a description of the current royalty scheme.

 

Our operations in Colombia are subject to extensive national, state and local environmental regulations. Environmental rules and regulations are applicable to our exploration, production, refining, transportation, supply and marketing activities, as well as the biofuels we produce. These regulations establish, among other things, quality standards for hydrocarbon products, air emissions and greenhouse gases, water discharges and waste disposal, soil remediation, water pollution and the general storage, handling, transportation and treatment of hydrocarbons in Colombia. Currently, all exploratory projects drilling in areas that do not yet have a license must undergo an environmental impact assessment and must receive an environmental license from the governmental agency responsible for awarding environmental licenses, the Environmental License National Agency or ANLA. Environmental authorities with jurisdiction over our activities routinely inspect our crude oil fields, refineries and other production sites, and they may decide to open investigations or sanction proceedings, which may result in the imposition of fines, restrictions on operations or other sanctions in connection with potential non-compliance with environmental laws.

 

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We are also subject to control and monitoring by the regional autonomous corporations, which are regional environmental authorities that grant permits for the use and exploitation of natural resources, establish compensation measures for the use of these resources, and perform monitoring, control and sanctions function.

 

If we fail to comply with any of these national or regional environmental regulations or authorities, we could be subject to administrative and criminal penalties, including warnings, fines or closure orders of our facilities. Any such criminal penalty would be imposed on the legal representatives of the Company, including any legal representative, director or worker who participated or failed to take action related to the activities that lead to environmental damage. See the section Business Overview—Applicable Laws and Regulations—Regulation of Exploration and Production Activities—Business Regulation—Environmental Licensing and Prior Consultation.

 

Environmental regulation has become more stringent in Colombia in recent years. As a result, our operating costs have increased in order to comply with these new technical environmental requirements as well as the need to strengthen our specialized team in charge of environmental compliance in project and operations. If environmental laws continue to impose additional costs on us, we may need to reduce our investments on strategic projects in order to allocate funds to environmental compliance. We are also exposed to delays in obtaining environmental licenses from ANLA, which can lead to cost overruns or to changes in our investment plans. These additional costs may have a negative impact on the profitability of the projects we intend to undertake or may make them economically unattractive, in turn having a negative impact on our results of operations and financial condition.

 

We are subject to foreign environmental regulations for the exploratory activities conducted by us outside Colombia. Failure to comply with foreign environmental regulations may result in investigations by foreign regulators, which could lead to fines, warnings or temporary suspensions of our operations, which could have a negative impact on our financial condition and results of operations.

 

Under certain of our credit agreements, we are under an obligation to comply with international environmental standards established by our lenders or by multilateral institutions. Failure to comply with such environmental standards could result in an event of default under the relevant credit agreements that we, or our subsidiaries, have entered into, which would affect our financial condition. For instance, the credit facility executed by Reficar for the financing of its expansion and modernization project includes an obligation to comply with the U.S.-Exim Environmental Procedures and Guidelines and the Organization for Economic Co-operation and Development (OECD) Common Approaches on Environment and Officially Supported Export Credits, and a credit agreement executed by Ecopetrol S.A. to finance purchases of U.S. goods and services requires Ecopetrol S.A. to comply with the U.S.-Exim Environmental Procedures and Guidelines.

 

In addition, we may be subject to foreign health and safety and environmental regulations for our exploratory activities conducted outside Colombia. Foreign health and safety regulations may be more severe than those established under Colombian law and, therefore, we may be required to make additional investments to comply with those regulations.

 

We may incur losses and spend time and money defending pending lawsuits and arbitrations.

 

We are currently a party to several legal proceedings filed against us. We are also subject to labor-related lawsuits filed by current and former employees in connection with pension plans and retirement benefits. For example, as of December 31, 2015, Ecopetrol S.A. was a party to 3,391 legal proceedings relating to civil, administrative, environmental, tax, and labor claims filed against us of which 310 met the accounting threshold for an accrual provision. We allocate substantial amounts of money and time to defend against these claims, in which the claimants often seek substantial sums of money as well as other remedies. See Note 23 – Accrued liabilities and provisions to our consolidated financial statements and see the section Risk Review—Legal Proceedings and Related Matters. In addition, in accordance with Colombian law, we are subject to surveillance and investigations by certain control entities in Colombia, which are intended to determine whether public funds have been misappropriated or whether they have been used in compliance with applicable law.  See the section Risk Review—Legal Proceedings and Related Matters.

 

5.1.4Risks Related to our ADSs

 

This section discusses potential risks associated with an investment in our American Depository Shares (as opposed to our common shares) by investors outside Colombia.

 

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Holders of our ADSs may encounter difficulties in protecting their interests.

 

Holders of our ADSs do not have the same voting rights as holders of our shares. As set forth in the deposit agreement, dated September 16, 2008, among Ecopetrol S.A., JP Morgan Chase Bank, N.A., as depositary, and all holders from time to time of our American Depositary Receipts (the “Deposit Agreement”), ADSs may instruct our current depositary, JP Morgan Chase Bank, N.A., to vote on shareholder matters prior to a shareholders’ meeting. Colombia law does not, however, require Ecopetrol to request proxies from existing shareholders. Thus, shareholders may not become aware of some matters in time to instruct the depositary to vote their shares.

 

The Deposit Agreement provides ADSs with the right to instruct the depositary to vote common shares separately. The viability of this contractual provision is unclear. This is because regulatory agencies have advanced inconsistent positions regarding whether a depository must vote common shares as a single block or may vote them separately. Going forward, the Colombian regulatory authorities may change their interpretation as to how the voting rights should be exercised by ADS holders, and such possible interpretation could adversely affect the value of the common shares and ADSs.

 

Our ADSs holders may be subject to restrictions on foreign investment in Colombia.

 

Colombia’s International Investment Statute (the set of rules and regulations which govern the foreign exchange market and the transactions thereto, which include Resolution 8 of 2000 and External Circular No. DCIN 83 issued by the Colombian Central Bank among others) regulates the manner in which non-Colombian residents can invest in Colombia and participate in the Colombian securities market. Among other requirements, Colombian law requires foreign investors to register certain foreign exchange transactions with the Colombian Central Bank and outlines the necessary procedures to authorize certain types of foreign investments. Colombian law requires that certain foreign exchange transactions, including international investment in foreign currency between Colombian residents and non-Colombian residents, must be made through authorized foreign exchange market participants. Any income or expenses under our American Depositary Receipt, or ADR, program must be made through the foreign exchange market.

 

Investors acquiring our ADRs are not required to register with the Colombian Central Bank, as they will benefit from the registration to be obtained by the custodian for our common shares underlying the ADRs in Colombia. If investors in ADRs choose to surrender their ADRs and withdraw common shares, they must register their investment in the common shares as a portfolio investment through their local representative, which may be a brokerage firm, trust company or investment management companies supervised by the Superintendency of Finance (Superintendencia Financiera de Colombia). Investors will only be allowed to transfer dividends abroad after their foreign investment registration procedure with the Colombian Central Bank has been completed. Investors withdrawing common shares could incur expenses and/or suffer delays in the application process. The failure of a non-resident investor to report or register foreign exchange transactions with the Colombian Central Bank relating to investments in Colombia on a timely basis may prevent the investor from remitting dividends, or initiate an investigation that may result in a fine. In the future, the Government, the Colombian Congress or the Colombian Central Bank may amend Colombia’s International Investment Statute or the foreign investment rules, which could result in more restrictive rules and could negatively affect trading of our ADSs.

 

Colombia currently has a free convertibility system. If a more restrictive convertibility system is implemented, the depositary may experience difficulties converting Colombian Peso amounts into U.S. dollars to remit dividend payments. Also, currently Colombia has a floating exchange rate system that might be subject to change in the future. See the section Shareholder Information—Exchange Controls and Limitations.

 

Holders of our ADSs may not be able to effect service of process on us, our directors or executive officers within the United States, which may limit your recovery in any foreign judgment you obtain against us.

 

We are a mixed economy company organized under the laws of Colombia. In addition, most of the members of our Board of Directors (“Directors”) and executive officers reside outside the United States. All or a substantial portion of our assets and the assets of these persons are located outside of the United States. As a result, it may not be possible for you to effect service of process within the United States upon us or these persons or to enforce judgments against us or them in U.S. courts obtained in such courts predicated upon the civil liability provisions of the U.S. federal securities laws. Colombian courts determine whether to enforce a U.S. judgment predicated on the U.S. securities laws through a procedural system known as exequatur. For a description of these limitations, see the section Shareholder Information—Enforcement of Civil Liabilities.

 

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The protections afforded to minority shareholders in Colombia are different from those in the United States, and may be difficult to enforce.

 

Under Colombian law, the protections afforded to minority shareholders are different from those in the United States. In particular, the legal framework with respect to shareholder disputes is substantially different under Colombian law than U.S. law and there are different procedural requirements for commencing shareholder lawsuits, such as shareholder derivative suits. As a result, it may be more difficult for our minority shareholders to enforce their rights against us or our Directors or controlling shareholder than it would be for shareholders of a U.S. company.

 

ADRs do not have the same tax treatment as other equity investments in Colombia.

 

Although ADRs represent Ecopetrol’s common shares, for Colombian tax purposes, ADRs are securities different from their underlying assets. Therefore, ADR holders are not entitled to the tax treatment granted to holders of the common shares. Such tax treatment includes, among others, those benefits relating to dividends and profits derived from sale of Colombian common shares. For further information see the section Shareholder Information—Taxation—Colombian Tax Considerations.

 

Judgments of Colombian courts with respect to our ADSs will be payable only in Colombian Pesos.

 

If proceedings are brought in the courts of Colombia seeking to enforce the rights of ADS holders of common shares, we will be required to discharge our obligation amounts in Colombian Pesos. Colombian law provides that an obligation in Colombia to pay amounts denominated in foreign currency may only be satisfied in Colombian currency at the Representative Market Exchange Rate of the date the judgment is obtained, and such amounts are then adjusted to reflect exchange rate variations through the effective payment date.

 

The relative volatility and illiquidity of the Colombian securities markets may substantially limit our investors’ ability to sell our ADSs at the price and time they desire.

 

Investing in securities that are traded in emerging markets, such as Colombia, often involves greater risk when compared with other world markets, and these investments are generally considered to be more speculative in nature.

 

The Colombian securities market is substantially smaller, less liquid, more concentrated and can be more volatile than other securities markets in the United States. The Colombian Stock Exchange (Bolsa de Valores de Colombia), or BVC, had a market capitalization of approximately COP$278,689 billion (US$88 billion using the closing rate for 2015) as of December 31, 2015, a 23% decrease when compared with the amount at the end of 2014, a daily average trading volume of approximately COP$136,468 million (US$49.74 million, using the average exchange rate for 2015), a 19% decrease when compared with the volume in 2014. By comparison, the New York Stock Exchange, or NYSE, had a market capitalization of US$17.8 trillion as of December 31, 2015, and a daily trading volume of approximately US$69.6 billion in 2015.

 

As of December 31, 2015, our shares represented the highest market capitalization of the BVC accounting for as of 16% of the total COLCAP index, which reflects the price volatility of the 20 most-liquid stocks.

 

Given the current ownership structure of our shares, it may be difficult for you to purchase large quantities of shares from a single shareholder. We cannot assure you that a liquid trading market for our ADSs will develop or, if developed, that it will be maintained. Without a liquid trading market, the ability of investors in our ADSs to sell them at the desired price and time could be substantially limited.

 

We are not required to disclose as much information to investors as a U.S. issuer is required to disclose.

 

We are subject to the reporting requirements of the Superintendency of Finance and the BVC. The corporate disclosure requirements that apply to us may not be equivalent to the disclosure requirements that apply to a U.S. issuer and, as a result, you may receive less interim information about us than you would receive from a U.S. issuer.

 

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5.1.5Risks Related to State Ownership

 

Our controlling shareholder’s interests may be different from those of our minority shareholders.

 

Colombian Law 1118 of 2006 requires the Nation to maintain the majority of our outstanding capital stock. The Nation currently holds 88.49% of our outstanding capital stock, making it our controlling shareholder. The Nation as our controlling shareholder has majority voting rights at the shareholders’ meeting to elect the members of our Board of Directors. The Nation may propose and approve decisions that are in its own interest and in furtherance of its own economic and political interests that do not necessarily benefit minority shareholders.

 

Our controlling shareholder may approve dividends at the ordinary general shareholders’ meeting, notwithstanding the interest of minority shareholders, in an amount that results in us having to reduce our capital expenditures, thereby negatively affecting our prospects, results of operations and financial condition. See the section Shareholder Information—Dividend Policy.

 

Additionally, given our controlling shareholder’s interests, it may undertake projects, approve decisions or make announcements about its intentions related to its holding of our capital stock which may not be in our best interest or in the best interest of our minority shareholders, including holders of our ADSs, and could impact the price of our shares or ADSs.

 

5.2Risk Management

 

5.2.1Managing Risk through our Internal Control System

 

With the creation of the Vice presidency of Compliance in 2015, Ecopetrol S.A. consolidated its internal control systems into an unified system that integrates the best practices called for by the Committee of Sponsoring Organizations of the Treadway Commission (COSO 2013), Sarbanes–Oxley Act (SOX), governance and management of enterprise IT (COBIT), Enterprise Risk Management (ERM) and our ethics and compliance rules, with the aim of establishing an integrated management system for all control components; thereby allowing us to strengthen all of our control system.

 

The main purpose of the Ecopetrol S.A.’s Internal Control System is to provide reasonable assurance regarding the achievement of all of the Company’s objective relating to operations, strategy, reporting and compliance, through the appropriate risks management and ensuring the effectiveness of its controls. The system performance is systematically monitored by the Board of Directors semiannually.

 

Ecopetrol S.A.’s Internal Control System is aligned to the Company’s strategy and business processes and gives responsibility to all employees to manage risk, to maintain the effectiveness of controls, to report of incidents and deficiencies and to ensure continuous improvement of the processes.

 

The risk management component of our Internal Control System is in charge of identifying events or situations that may affect our defined objectives, assessing and prioritizing them to implement the most appropriate response. This component has been designed and implemented across the organization, with a two-level focus: Enterprise Risk and Risk in Processes.

 

(i)Enterprise Risks: Are those risks that are directly associated with the business strategy plan of the Company and are systematically monitored by the Enterprise Management Committee on a monthly basis. The management of those risks is led by a member of the Enterprise Management Committee; and each risk has a defined treatment plan and monitoring indicators.

 

(ii)Risks in Processes: Are those risks that tend to identify potential failures in the activities related to our core and support business processes that drive us to achieve of our strategic objectives. At this level, each process has is owns identified risks with respective mitigation methods, including financial and non-financial control, treatment plans and/or monitoring indicators.

 

Our risk management approach is based around the risk management cycle, consisting in five main stages: planning, identifying, evaluating, treatment and monitoring risks, as well as communication across stages. This cycle is supported in three pillars of risk management: culture, organizational structure and normative and management tools.

 

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Three of our most important tools within the risk management component are:

 

(i)Risk Assessment Methodology: in order to properly prioritize mitigation, treatment and monitoring efforts of risk management at the process level, a standardized methodology was established to assess inherent and residual risk levels. The risk level (Very High, High, Medium, Low or None) is obtained from the combination of the consequences (impacts) and the probability of occurrence of those consequences. According with the level of risk, action plans for management and mitigation are defined.

 

(ii)Treatment Plans: Each year, in the risk management cycle, we define and implement treatment plans in order to reduce the levels of exposure to risk through mitigation or elimination of some of its causes. Metrics and goals must be defined during the development of each plan to ensure its effectiveness and to prioritize our efforts on those with the greatest impacts.

 

(iii)Monitoring Indicators: As part of the monitoring stage of the risk management cycle, Ecopetrol has implemented Key Risk Indicators (KRIs) which are metrics used to provide early signals of increasing risk exposures. These signals constitute information for proactive decision making in order to avoid risk materialization.

 

Ecopetrol S.A. has defined guidelines and minimum requirements to implement an Internal Control System framework for its subsidiaries. These guidelines provide different classifications according to three important variables: the size of the organizational structure, the scope of SOX and the asset value of each subsidiary. The classification of each subsidiary determines the scope of implementation (Basic, Intermediate and Complete) of our Internal Control System. Under those guidelines, each subsidiary must report its performance to its enterprise management committee, audit committee, or board of directors (or whoever is acting on their behalf). In addition, they have to report it annually to Ecopetrol S.A. To ensure compliance with the above measures, the subsidiaries have methodological support from Ecopetrol S.A. when it is requested.

 

5.2.2Managing Information Security and Cybersecurity

 

Ecopetrol S.A. has a dedicated management team focused on information security issues such as the treatment of information, safe information management practices, classification of critical business information, control systems compliance and effectiveness of available information security technologies, all of which are articulated with the ERM system at the enterprise level.

 

Ecopetrol S.A. has recently reviewed its cybersecurity exposure risks. During 2014, a working group was formed, led by our Vice-president of Innovation and Technology and with the participation of managers of industrial control systems (SCADA systems), informatics and information security, with the purpose of identifying our cybersecurity risks.

 

Although Ecopetrol S.A. is still at an early stage of managing its cybersecurity risks, our Vice-presidency of Innovation and Technology has begun a process of socialization and involvement with the higher-level of the organization, such as the audit and risk committee of the Board of Directors, to which a report was presented summarizing the most relevant aspects of our cyber security issues. As a result of this process, we are currently reviewing the feasibility of incorporating elements and strategic tools to the management of the cyber security threat; including, among others, policies, cybersecurity insurance coverage, and specialized monitoring and control mechanisms.

 

Currently, Ecopetrol S.A. is implementing a Security Operations Center service, which will enhance our ability to foresee and identify trends in attacks in Ecopetrol S.A.’s information technology infrastructure.

 

In addition, Ecopetrol S.A. shares information with the Cyber Defense Command Unit (Comando Conjunto Cibernético) an entity under the control of the Ministry of Defense, through which the national government is monitoring cyber security themes, in order to have a clearer view of the scope of protection required in these infrastructures.

 

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5.2.3Managing Financial Risk

 

We are exposed to certain risks associated with the nature of our operations and the financial instruments we use. Among the risks that affect our financial assets, liabilities and expected future cash flows are changes in commodity prices, currency exchange rates, interest rates and the credit quality of our counterparties.

 

Commodity price risk is associated with our day-to-day operations as we export and import crude oil, natural gas and refined products. We occasionally use hedges attached to cash flows to protect our financial results from price fluctuations. Part of our financial exposure under purchase contracts for crude oil and refined products with certain of our business partners and third parties depends on international oil prices. We believe that the risk of such exposure is naturally hedged since we either export crude oil at international market prices or sell refined products at prices that are correlated to international market prices. We do not use derivative financial instruments for speculative or profit-generating purposes.

 

Currency risk arises in our operations given the fact that most of our revenues are derived from sales of products quoted in or with reference to U.S. dollars. Therefore when the Colombian Peso depreciates against the U.S. dollar, our revenues converted into Colombian Pesos, increase. Conversely, when the Colombian Peso appreciates against the U.S. dollar, our revenues decrease. On the other hand, imported goods, oil services and the debt, which is mainly denominated in U.S. dollars, become less expensive when the Colombian Peso appreciates against the U.S. dollar and more expensive when the Colombian Peso depreciates against the U.S. dollar.

 

As of December 31, 2015 our dollar-denominated total debt was US$14.6 billion, which we recognize in our consolidated financial statements at its amortized cost, which corresponds to the present value of cash flows, discounted at the effective interest rate. Out of this total, US$11.1 billion relate to Ecopetrol S.A, whose functional currency is the Colombian Peso. Some of the group´s affiliates have the U.S. dollar as functional currency and are not exposed to exchange rate risk. On the asset side, when the financial statements of the Group are consolidated, the exchange rate differential of the affiliates whose functional currency is the U.S. dollar is recognized directly in equity, as part of other comprehensive income.

 

Taking previous considerations into account, Ecopetrol seeks to identify and manage currency risk in a comprehensive manner, using an integrated analysis of natural hedges in order to benefit from the correlation between income, expenses and debt denominated in foreign currency. In addition, the risk management strategy of the Company may involve the use of financial derivative instruments, and non-derivative financial instruments. As of October 1, 2015, Ecopetrol S.A. adopted hedge accounting as part of its risk management strategy, using the natural hedge between exports and dollar-denominated debt. 49% of Ecopetrol S.A’s debt in U.S. dollars is designated as hedge instrument of its future export sales for the period 2015- 2023 (see Note 4.1.4 to our financial statements for further explanation of the accounting policy and Note 31.2.1 for details of the hedge accounting adopted). With the adoption of hedge accounting, the effect of volatility of foreign exchange rate on the hedged portion of the debt is recognized directly in equity, as part of other comprehensive income. The remaining portion of Ecopetrol S.A.´s dollar-denominated debt continues exposed to the fluctuation of the exchange rate. Finally, the Company maintains enough cash in Colombian Pesos and U.S. dollars to meet its expenses in each currency.

 

Interest rate risk arises from our exposure to changes in interest rates mainly as a result of the issuances of floating rate debt linked to LIBOR (17.5%), DTF (9.0%) and CPI (3.6%) rates. Thus, volatility in interest rates may affect the fair value of and cash flows related to our investments and floating rate debt. In 2015, our analysis of credit risk events and global financial markets drove us to decide not to hedge interest rate risk. Nevertheless, our treasury office continuously monitors the performance of interest rates and the effect of interest rates on our financial statements.

 

The trust funds linked to Ecopetrol S.A.’s pension obligations (PAP) are also exposed to changes in interest rates, as they include fixed- and floating-rate instruments that are mark to market. This exposure is continuously monitored by our treasury office given the potential impact volatility may have on our financial results. The treasury office’s information is gathered from reports provided by the asset managers. These reports refer to regulatory limits as well as market, credit and liquidity risks. The investment guidelines with respect to the PAPs are issued by the Colombian regulation for pension funds, as stipulated in the Decree 941 of 2002 and Decree 1861 of 2012, where it is indicated that they have to follow the same regime as the regular obligatory pension funds in their moderate (i.e., neither conservative nor aggressive) portfolio. For further information regarding the trust funds linked to the pension obligations of the company, see Note 22.2 Plan assets to our consolidated financial statements.

 

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Finally, counterparty risk is the potential probability that a borrower or counterparty defaults on any obligation. In our case, we are exposed to this risk as we invest in different financial instruments and receive letters of credit in order to mitigate our exposure with our commercial counterparties. We manage this risk through an analysis of an issuer’s creditworthiness, stock price behavior, spreads on credit default swaps and the probability of default.

 

Investment Guidelines

 

Ecopetrol S.A.

 

Following the promulgation of Decree 1525 of 2008, which provides general rules on investments for public entities, Ecopetrol S.A.’s management established guidelines for our investment portfolios. These guidelines determine that investments in Ecopetrol S.A.’s U.S. dollar portfolio are generally limited to investments of our excess cash in fixed-income securities issued by entities rated A or higher in the long term and A1/P1/F1 or higher in the short term (international scale) by Standard & Poor’s Ratings Services, Moody’s Investors Service or Fitch Ratings. In addition, Ecopetrol S.A. may also invest in securities issued or guaranteed by the U.S. government or Colombian government, without regard to the ratings assigned to such securities. In Ecopetrol S.A.’s Colombian Peso portfolio, it must invest our excess cash in fixed-income securities of issuers rated AAA in the long term, and F1+/BRC1+ in the short term (local scale) by Fitch Ratings Colombia or BRC Standard & Poor’s. In addition, Ecopetrol S.A. may also invest in securities issued or guaranteed by the Colombian government without rating restrictions.

 

In order to diversify risk in our Colombian Peso portfolio, Ecopetrol S.A. does not invest more than 10% of the excess of cash in one specific issuer. In the case of our U.S. dollar portfolio, it does not invest more than 5% of the excess of cash in one specific issuer in the short term (up to one year), or 1% in the long term.

 

Ecopetrol S.A.’s investment portfolio in U.S. dollars is segmented into four tranches, each one matching our liquidity needs. The working capital tranche is calculated taking into account our cash flow needs for the next 60 days. The liquidity tranche is calculated as the contingent cash flow needs over the working capital, taking into account the development of capital expenditures related to projects. The asset liability tranche is built to match our long-term debt. The investment tranche includes the remaining amount of the total portfolio after deducting the amounts pertaining to the above mentioned tranches and after subtracting the Colombian Peso portfolio.

 

Ecopetrol S.A.’s investment portfolio in Colombian Pesos is segmented in two tranches, each one matching our liquidity needs. The first tranche is calculated taking into account our cash flow needs for the next 30 days, and the second tranche is built for investment purposes.

 

5.3Legal Proceedings and Related Matters

 

We are a party to various legal proceedings in the ordinary course of business. Other than the proceedings disclosed in this annual report, we are not involved in any pending (or, to our knowledge, threatened) litigation or arbitration proceeding that we believe will have a material adverse effect on our Company. Other legal proceedings that are pending against or involve us and our subsidiaries are incidental to the conduct of our and their business. We believe that the ultimate disposition of such other proceedings individually or in an aggregate basis will not have a material adverse effect on our consolidated financial condition or results of operations.

 

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As of December 31, 2015, Ecopetrol S.A. was a party to 3,391 legal proceedings relating to civil, administrative, environmental, tax and labor claims filed against us in the Colombian courts and arbitration tribunals, of which 310 had an accrual provision. We allocate sufficient amounts of money and time to defend these claims. Historically, we have been successful in defending lawsuits filed against us. Other than the environmental administrative proceedings described in the last paragraph of this section, based on the advice of our legal advisors, it is reasonable to assume that the litigation procedures brought against us will not materially affect our financial position or solvency regardless of the outcome. See Note 23 – Accrued liabilities and provisions to our consolidated financial statements included in this annual report for a discussion of our legal proceedings.

 

Caño Limón – Coveñas Crude Oil Pipeline Spill

 

On December 11, 2011, the Caño Limón-Coveñas oil pipeline ruptured and caused the spill of approximately 3,267 barrels of crude oil into the Iscala creek, which connects with the Pamplonita River that provides water to the city of Cúcuta. The incident did not cause any fatalities or injuries.

 

We launched an internal investigation and hired a highly renowned international consultant to investigate the causes of this incident. The conclusion of the investigations was that the rupture occurred as a result of an unusual movement of soil and the tensioning of the pipeline.

 

A class action lawsuit has been filed against Ecopetrol S.A. and against employees of the company, and the First Administrative Court of Cucuta has jurisdiction to conduct the case, which is in the probatory stage.

 

The Regional Environmental Authority of Norte de Santander, or Corporación Autónoma Regional de la Frontera Nororiental – CORPONOR, initiated an investigation into the causes of the incident and also initiated enforcement actions against us for the allegedly wrongful implementation of the contingency plan. These proceedings were assumed by the National Authority on Environmental Licensing – ANLA according to national jurisdiction rules. As of the date of this annual report, the Agency has ceased all efforts on the aforementioned investigation and has not opened a new investigation.

 

The Colombian General Comptroller’s Office initiated an investigation to determine whether Ecopetrol’s President, the Vice-president of Transportation, and two other employees of the company should be held financially liable for the Caño Limón-Coveñas pipeline spill and consequently for having caused a decrease in the assets of Ecopetrol. On November 26, 2015, the investigation ended in favor of the aforementioned employees.

 

CORPONOR has filed a lawsuit against Ecopetrol at the First Administrative Court of Cucuta claiming for (i) the environmental loss caused by the incident and (ii) for compensation costs relating to the environment damage for approximately COP$33 billion. Ecopetrol’s legal counsel filed to dismiss the lawsuit on June 2, 2014, based on three grounds: (i) there is no proof of environmental loss, (ii) CORPONOR does not have the authority to file this lawsuit and (iii) CORPONOR’s petition for direct compensation is not the proper legal action according to the applicable procedural rules.

 

Ecopetrol and national and local authorities are developing a project for the development of an alternative to the water supply in the intake of the aqueduct in Cúcuta, which was approved by the Company’s Board of Directors in December 2011 as part of the strengthening of its contingency plans and its relationship with its stakeholders. At the time of this report the project is still in the planning stage.

 

BT Energy Challenger

 

On October 22, 2014, we were served with a class action suit against us seeking monetary damages of approximately COP$7.4 trillion related to an incident that occurred on August 21, 2014, during the loading operations of the BT Energy Challenger vessel. The claimants alleged possible damage to the port area of Ecopetrol’s terminal in Coveñas, as well as of marine and submarine areas and beaches that form the geographical area of the Morrosquillo Gulf. This allegation is currently under investigation by the Harbor Master of Coveñas. Ecopetrol filed a motion requesting the judge to require the claimants to amend their claim to more precisely set forth the facts and evidence it believes establishes Ecopetrol’s liability.

 

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On March 3, 2015, Ecopetrol filed its statement of defense arguing the exclusive fault of a third party. On October 20, 2015, the Court denied a class of more than 100 informal traders in the region because there is no common identity with the initial class (hotel employees).

 

At the date of this report, Ecopetrol is waiting for the Court to designate a legal representative for the defendants.

 

PetroTiger

 

As highlighted in previous 20-F and 6-K filings, on January 6, 2014, the United States Department of Justice (DOJ) announced the unsealing of charges against two former co-chief executive officers (CEOs) and the former general counsel of PetroTiger Ltd. (PetroTiger), alleging, among other things, violations of the U.S. Foreign Corrupt Practices Act (FCPA) and conspiracy to commit violations of the FCPA and money laundering in connection with payments made to an Ecopetrol employee. By the time of the DOJ announcement, that employee no longer worked at the Company. The DOJ alleged the payments were made to secure Ecopetrol’s approval for PetroTiger’s entry into an oil services contract with Mansarovar Energy Colombia Ltd. Ecopetrol participated in the Mansarovar project as non-operating partner in a joint operating agreement. Also on January 6, 2014, the DOJ announced that the general counsel of PetroTiger had pled guilty on November 8, 2013, to one count of conspiracy to violate the FCPA and to commit wire fraud. One of the charged former co-CEOs pleaded guilty on February 18, 2014, to the same charge. On May 9, 2014, the DOJ charged the other former co-CEO with conspiracy to violate the anti-bribery provisions of the FCPA, conspiracy to commit wire fraud, conspiracy to launder money, and substantive FCPA anti-bribery and money laundering violations. On June 15, 2015, that co-CEO pleaded guilty to conspiracy to violate the FCPA.

 

After the DOJ unsealed its charges on January 6, 2014, Ecopetrol filed a complaint the same month, jointly with the Transparency Secretariat of the Presidency of the Republic, to Colombia’s Attorney General’s office requesting the investigation of individuals who may have been involved in the wrongdoing related to the Mansarovar contract. Colombian authorities initiated a proceeding related to PetroTiger, and on March 11, 2015, arrested four current Ecopetrol employees and two former Ecopetrol employees related to their investigation of the Mansarovar project and five other contracts involving PetroTiger and Ecopetrol.

 

Ecopetrol has responded to information requests from the DOJ and Colombian authorities in connection with their investigations of PetroTiger. Ecopetrol has been designated with the formal status of victim in the local Colombian proceedings. It has terminated the employment of the four charged individuals who were Ecopetrol employees at the time of the arrests.  Ecopetrol is conducting an internal investigation focused on issues identified in the U.S. and Colombian proceedings and, upon completion of that investigation, will evaluate any further measures.

 

Salgar-Cartago Multipurpose Pipeline Spill

 

On December 23, 2011 our Salgar-Cartago pipeline ruptured. Internal and external experts believe this incident occurred as a result of creep movement of soil caused by severe weather conditions, causing the soil surrounding the pipeline to exert strong pressure on the pipeline and rupture it. Due to the rupture, approximately 59,976 U.S. gallons of gasoline spilled into the surrounding area in La Divisa and Villa Carola in the Municipality of Dosquebradas, Risaralda. The spilled gasoline from the pipeline subsequently came into contact with a heat source which ignited it, causing several explosions that tragically resulted in 33 fatalities and 35 injuries, as well as damage to the neighboring houses and buildings. In January 2012, we launched the Dosquebradas Project to address the effects of the incident, and as of the date of this annual report the project’s health, legal, environmental and social components have been successfully completed.

 

As of the date of this annual report, nine lawsuits related to this incident for approximately COP$19 billion worth of damages are active.

 

Environmental Administrative Proceedings

 

As of December 2015, Ecopetrol S.A. was party to 190 environmental administrative proceedings, of which 163 were initiated before 2014, and 27 during 2015. During 2015, nine proceedings were concluded, in two of them we were subject to monetary fines. It is not possible for us to determine whether the pending proceedings could have a material effect on Ecopetrol.

 

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Reficar Investigations

 

Ecopetrol is a corporation majority owned by the Government that administers public resources. Since the Government is Ecopetrol’s majority shareholder, Ecopetrol’s employees have a statutory responsibility to ensure the proper use of public resources. Reficar, as a subsidiary of Ecopetrol, and its employees, are also responsible for the management of the public resources under Reficar’s management.

 

The acts of Ecopetrol’s and Reficar’s functionaries are currently, subject to the control and supervision of the following control entities, among others:

 

·The Office of the General Comptroller (Contraloría General de la Nación) is the entity entrusted to ensure the proper use of public resources and has the authority to investigate government employees or private sector employees that use or manage public resources.

 

·The Office of the Attorney General (Procuraduria General de la Nación) is the entity in charge of supervising government employees and non-government employees that undertake public functions and that manage public funds and their compliance with the constitution, law, judicial decisions and administrative acts.

 

·The Prosecutor’s Office (Fiscalia General de la Nación) is the entity in charge of investigating crimes and prosecuting those crimes before the court in judicial proceedings.

 

As a result of the delays and cost overruns experienced by the Cartagena refinery expansion Project (“Project”), the Office of the General Comptroller initiated a review of Reficar in 2015, which was concluded and published in 2016. While its report does not mention any judicial findings against Reficar, it did lead to the initiation of a special audit investigation into the Project. As of the date of this annual report, the investigation is underway, with the Office of the General Comptroller currently in the preliminary stage of gathering information.  Ecopetrol and Reficar are fully cooperating with the Office of General Controller in providing all information requested to date. As of the date of this annual report, Ecopetrol has no knowledge of specific investigations against employees of Reficar or Ecopetrol by the Office of the General Comptroller.

 

The Office of the Attorney General currently has two open investigations relating to Reficar matters: (i) one initiated in 2012 against members of Reficar’s board of directors at the time as well as certain current and former officers of Reficar; and (ii) a more recent investigation into delays in the completion of the Reficar modernization and expansion project and into current and former officers of Ecopetrol as well as current and former members of Ecopetrol’s Board of Directors, including Juan Carlos Echeverry, Ecopetrol’s current Chief Executive Officer, who served as Ministry of Finance between February of 2010 and September of 2012, and in that capacity was a member of our Board of Directors.

 

Additionally, in early February 2016, the Prosecutor’s Office carried out an information assurance procedure at Reficar’s offices and is currently in the process of gathering and reviewing information about Reficar.

 

All the investigations mentioned above are still in their preliminary stages.  Ecopetrol and Reficar are giving high importance to these processes through their extensive and close cooperation with the control entities.  Ecopetrol has appointed a manager to gather all the information related to the project in order to guarantee its integrity and organization. Likewise, Ecopetrol has designated a spokesperson to liaise with the control entities for the procurement of information. As of the date of this annual report, Ecopetrol and Reficar are undertaking an internal investigation, but none of the investigations allege yet any violations to the Code of Ethics and nor do they affect the integrity of Ecopetrol's businesses.

 

Finally, it is worth noting that Reficar filed a Request for Arbitration with the International Chamber of Commerce against Chicago Bridge & Iron Company N.V., CB&I (UK) Limited, and CBI Colombiana S.A. (collectively, “CB&I”) with respect to the Engineering, Procurement, and Construction Contract entered into by and between Reficar and CB&I for the expansion of the Cartagena Refinery in Cartagena, Colombia. Reficar is the Claimant in the ICC arbitration proceeding and seeks no less than US$2 billion from CB&I.

 

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6.Shareholder Information

 

6.12016 Shareholders’ General Assembly

 

Our Shareholders’ General Assembly was held on March 31, 2016. In it, the following matters were approved:

 

·The declaration of the non-payment of a cash dividend for the fiscal year ended December 31, 2015.

 

·The designation of the firm Ernst & Young Ltda. as the Company’s fiscal auditor for 2016.

 

·The new composition of the Board of Directors for the year 2016.

 

6.2Dividend Policy

 

We do not have a dividend policy. Pursuant to Colombian law, dividend distribution to our shareholders must be approved by a 78% majority of the shares represented in the corresponding shareholders’ meeting. In the absence of this special majority, at least 50% of the net profits must be distributed. In 2013, 2014 and 2015 the shareholders approved the distribution of 79.9%, 80.1% and 70% of 2012, 2013 and 2014 net income, respectively. Given that the fiscal year ended December 31, 2015 resulted in a net loss for Ecopetrol S.A., our shareholders at the Ordinary General Stockholder Meeting held on March 31, 2016, have approved that there will be no distribution of profits for the fiscal year ended December 31, 2015. Pursuant to Article 456 of the Code of Commerce the Company will absorb the net loss for the fiscal year ended December 31, 2015 through its legal reserve. See the section Financial Review—Liquidity and Capital Resources—Dividends.

 

Ecopetrol S.A. is required to have legal reserves equal to 50% of its subscribed capital. If the legal reserves are less than 50% of subscribed capital, we will contribute 10% of net income to our legal reserves every year until our legal reserves meet the required level.

 

6.3Market and Market Prices

 

In August 2007, we conducted an initial public offering of 10.1% of our common shares in Colombia. As a result of such offering, our common shares have traded on the Colombia Stock Exchange (Bolsa de Valores de Colombia) or BVC since November 2007 under the symbol “ECOPETROL.” Our ADSs, representing 20 common shares, have been traded on the NYSE under the symbol “EC” since September 2008. JPMorgan Chase Bank, N.A. serves as depositary for our ADSs.

 

Starting on August 2010, our ADSs began trading on the Toronto Stock Exchange (“TSX”) under the symbol “ECP.” On February 17, 2016, we announced the application for voluntary delisting from the Toronto Stock Exchange after in an ordinary meeting held on January 27, 2016, during which the Board of Directors made the decision to delist from the TSX. This decision was based on the Board of Director’s assessment of, among other factors, the limited trading activity of our ADRs in Canada, a liquid market for our ADRs on the NYSE and for our ordinary shares on the local Colombian Stock Exchange (Bolsa de Valores de Colombia), both of which enable interested investors to acquire a participation in Ecopetrol S.A. The time and administrative efforts associated with maintaining the listing of the ADRs on the TSX were also taken into account. On March 2, 2016, Ecopetrol’s ADRs were delisted from the TSX. After delisting from the TSX, the ADRs have continued to trade on the NYSE and the ordinary shares have continued to trade in the Colombian stock market. Therefore, the Company continues to be subject to United States as well as Colombian reporting and corporate governance obligations.

 

The second round of the equity offering program took place between July 27 and August 17, 2011. The offer was directed exclusively to investors in Colombia as permitted by Law 1118 of 2006. A total of 644,185,868 shares were allotted, equivalent to approximately COP$2.38 trillion. Out of the 219,054 investors participating in this round, 73% were new stockholders. In addition, 87% of the offering was allocated to retail investors and the remaining 13% to institutional investors. Funds obtained by us through this offering were allocated to the Company’s investment plan.

 

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In the future, the Nation (via the Ministry of Finance and Public Credit), as our controlling shareholder, may make decisions or announcements about its intention to sell part of its holding of our capital stock. We understand that our cooperation is necessary for the successful coordination of the Nation’s process.

 

The following table sets forth reported high and low closing prices in Colombian Pesos for our shares and the reported average daily trading volume of our shares on the BVC for the periods indicated. The table also sets forth information on the trading price of our shares in Colombian Pesos and U.S. dollars, as well as the average trading volume.

 

Table 60 – Shares Traded on the Bolsa de Valores de Colombia

 

   Shares Traded on the BVC 
   Colombian Pesos per share  

U.S. dollars per share(1)

   Average
number of
shares traded
 
   High   Low   High   Low   Per day 
2011   4,300    3,575    2.2823    1.9466    6,750,979 
2012   5,850    4,200    3.3236    2.1619    8,396,801 
2013   5,710    3,695    3.2091    1.8992    7,018,859 
2014   4,030    1,815    2.0556    0.7546    8,222,596 
2015   2,305    1,090    0.8402    0.3973    10,109,301 
Most recent quarters                         
First quarter 2014   4,030    3,390    2.0506    1.6755    7,720,085 
Second quarter 2014   4,030    3,410    2.0556    1.7042    7,977,622 
Third quarter 2014   3,380    3,110    1.8092    1.4223    7,405,784 
Fourth quarter 2014   3,140    1,815    1.5529    0.7546    9,767,957 
First quarter 2015   2,305    1,800    0.9335    0.7289    12,054,021 
Second quarter 2015   2,085    1,625    0.8337    0.6497    10,056,874 
Third quarter 2015   1,675    1,285    0.5706    0.4377    9,516,211 
Fourth quarter 2015   1,515    1,090    0.4953    0.3563    8,805,595 
First quarter 2016   1,425    881    0.4386    0.2712    17,971,092 
Most recent six months                         
October 2015   1,515    1,320    0.5170    0.4506    9,508,371 
November 2015   1,415    1,295    0.4715    0.4315    10,474,905 
December 2015   1,285    1,090    0.3961    0.3360    6,481,834 
January 2016   1,110    881    0.3394    0.2694    11,218,928 
February 2016   1,165    993    0.3472    0.2960    20,524,902 
March 2016   1,425    1,170    0.4554    0.3739    21,704,147 
April 2016 (through April 22, 2016)   1,435   1,220    0.4746    0.4035    18,286,408 

 

 

(1)U.S. dollars per common share translated at the Representative Market Exchange Rate as of each period.

 

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The following table sets forth reported high and low closing prices in U.S. dollars for our ADSs and the average daily trading volume of our ADSs on the NYSE for the periods indicated. The table also sets forth information on the trading price of our ADSs in U.S. dollars, as well as the average trading volume.

 

Table 61 – Shares Traded on the New York Stock Exchange

 

   ADSs Traded on NYSE 
  

U.S. dollars per ADS(1)

   Average number of 
   High   Low   ADSs Traded per day 
2011   46.00    38.47    357,289 
2012   67.48    44.52    551,410 
2013   63.80    37.93    464,193 
2014   41.16    14.77    603,083 
2015   19.80    6.50     960,193 
Most recent quarters               
First quarter 2014   40.79    33.20    624,531 
Second quarter 2014   41.16    34.05    468,611 
Third quarter 2014   36.39    28.60    425,034 
Fourth quarter 2014   30.94    14.77    892,769 
First quarter 2015   19.80    13.89    1,083,162 
Second quarter 2015   17.48    12.85    809,096 
Third quarter 2015   12.72    8.28    915,918 
Fourth quarter 2015   10.63    6.50    937,078 
First quarter 2016    9.22    5.40    1,559,605 
Most recent six months               
October 2015   10.63    8.57    921,035 
November 2015   10.09    8.39    944,651 
December 2015   8.28    6.50    946,236 
January 2016   7.01    5.40    1,251,680 
February 2016   7.08    5.83    1,563,856 
March 2016   9.22    7.28    1,821,675 
April 2016 (through April 22, 2016)    9.80    7.89    1,538,012 

 

 

(1)Each ADS represents the right to receive 20 of our common shares.

 

TRADING ON THE COLOMBIA STOCK EXCHANGE

 

The BVC is the largest stock exchange in Colombia for trading securities and derivatives. The BVC is a member of the World Federation of Exchanges and the Federación Iberoamericana de Bolsas.

 

The BVC is the only exchange where our common shares trade in Colombia. The table below sets forth the reported aggregate market capitalization of the companies traded on the BVC, as of December 31, 2015.

 

Table 62 – Market Capitalization of the Bolsa de Valores de Colombia

 

   Aggregate Market Capitalization of the BVC 
   Market Capitalization
(COP$ in billions)
  

Market Capitalization
(US$ in billions)(1)

 
December 31, 2015   278,689    17.78 

 

 

(1)Representative Market Exchange Rate as of December 30, 2015.

 

Registration and Transfer of Shares

 

Under Colombian law, transfers of shares must be registered on the issuer’s stock ledger. Only those holders registered on the stock ledger are considered by law as shareholders. Ecopetrol’s shares are in electronic form, other than those shares held by the Nation, which are in physical form.

 

Transfers of shares evidenced in electronic form required to be negotiated through the Colombia Stock Exchange. In Colombia, only the relevant stockbrokers called sociedades comisionistas de bolsa are authorized to make the transfers of shares through the Colombia Stock Exchange. The transfers of shares are registered in the Centralized Security Deposit (Depósito Centralizado de Valores) or DECEVAL, through the relevant stockbrokers. DECEVAL records the share transfer on its systems, in order to make the corresponding registration in the issuer stock ledger.

 

Under Colombian legislation, if a transfer of shares for a value equivalent to or higher than 66,000 UVR (the UVR was 228.2684 as of December 31, 2015) must be made through the BVC if the shares are registered with the BVC. Otherwise, shareholders can freely negotiate a transfer of shares.

 

Nevertheless, the following transfers are not required to be executed through the BVC:

 

·Transfers between shareholders who are considered to be the same beneficial owner;

 

·Transfers of shares owned by financial institutions, under supervision of Superintendency of Finance, that are in a liquidation process;

 

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·Repurchases of shares by the issuer;

 

·Property delivered in lieu of payment, or payment of money or other valuable property, different than the amount owed or demanded, in exchange for the extinguishment of the debt;

 

·Transfers of shares made by the Nation or the Financial Institutions Warranty Fund (Fondo de Garantías de Instituciones Financieras) or FOGAFIN;

 

·Transfers of shares issued abroad by Colombian companies, provided they take place outside Colombia;

 

·Transfers of shares issued by foreign companies, offered through a public offer in Colombia, provided that they take place outside Colombia; and

 

·Any other transaction specifically authorized by the Superintendency of Finance to take place outside the BVC.

 

For the purposes described above, multiple transfer transactions made within one hundred twenty (120) calendar days, between the same parties on shares of the same issuer and under similar conditions, are treated as a single transfer.

 

6.4Ecopetrol ADR Program Fees

 

Fees and Charges That a Holder of Our ADSs May Have to Pay, Either Directly or Indirectly

 

JPMorgan Chase Bank, N.A., our Depositary, may charge each person to whom ADSs are issued, including, without limitation, issuances against deposits of shares, issuances in respect of share distributions, rights and other distributions, issuances pursuant to a stock dividend or stock split declared by us or issuances pursuant to a merger, exchange of securities or any other transaction or event affecting the ADSs or deposited securities, and each person surrendering ADSs for withdrawal of deposited securities in any manner permitted by the Deposit Agreement or whose ADRs are cancelled or reduced for any other reason, US$5.00 for each 100 ADS (or any portion thereof) issued, delivered, reduced, cancelled or surrendered, as the case may be. The Depositary may sell (by public or private sale) sufficient securities and property received in respect of a share distribution, rights and/or other distribution prior to such deposit to pay such charge.

 

The Depositary collects its fees for issuance and cancellation of ADSs directly from investors depositing shares or surrendering ADSs for the purpose of withdrawal or from intermediaries acting for them. The Depositary collects fees for making distributions to investors by deducting those fees from the amounts distributed or by selling a portion of distributable property to pay the fees. The Depositary may collect its annual fee for Depositary services by deduction from cash distributions, or by directly billing investors, or by charging the book-entry system accounts of participants acting for them. The Depositary may generally refuse to provide services to any holder until the fees and expenses owing by such holder for those services or otherwise are paid.

 

The following additional charges may be incurred by ADS holders, by any party depositing or withdrawing shares or by any party surrendering ADSs or to whom ADSs are issued (including, without limitation, issuance pursuant to a stock dividend or stock split declared by us or an exchange of stock regarding the ADRs or the deposited securities or a distribution of ADSs), whichever is applicable:

 

·A fee of US$1.50 per ADR or ADRs for transfers of certificated or direct registration ADRs;

 

·A fee of up to US$0.02 per ADS for any cash distribution made pursuant to the Deposit Agreement;

 

·A fee of US$0.05 per ADS per calendar year (or portion thereof) for services performed by the Depositary in administering our ADR program (which fee may be charged on a periodic basis during each calendar year and shall be assessed against holders of ADRs as of the record date or record dates set by the Depositary during each calendar year and shall be payable in the manner described in the next succeeding provision);

 

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·Any other charge payable by the Depositary, or any of the Depositary’s agents, including, without limitation, the custodian, or the agents of the Depositary’s agents in connection with the servicing of our shares or other deposited securities (which charge shall be assessed against registered holders of our ADRs as of the record date or dates set by the Depositary and shall be payable at the sole discretion of the Depositary by billing such registered holders or by deducting such charge from one or more cash dividends or other cash distributions);

 

·A fee for the distribution of securities (or the sale of securities in connection with a distribution), such fee being in an amount equal to the fee for the execution and delivery of ADSs which would have been charged as a result of the deposit of such securities (treating all such securities as if they were shares) but which securities or the net cash proceeds from the sale thereof are instead distributed by the Depositary to those holders entitled thereto;

 

·Stock transfer or other taxes and other governmental charges;

 

·Cable, telex and facsimile transmission and delivery charges incurred at the ADS holder’s request;

 

·Transfer or registration fees for the registration of transfer of deposited securities on any applicable register in connection with the deposit or withdrawal of deposited securities;

 

·Expenses of the Depositary in connection with the conversion of foreign currency into U.S. dollars; and

 

·Such fees and expenses as are incurred by the Depositary (including, without limitation, expenses incurred in connection with compliance with foreign exchange control regulations or any law or regulation relating to foreign investment) in delivery of deposited securities or otherwise in connection with the Depositary’s or its custodian’s compliance with applicable laws, rules or regulations.

 

We will pay all other charges and expenses of the Depositary and any agent of the Depositary (except the custodian) pursuant to agreements from time to time between us and the Depositary. The fees described above may be amended from time to time.

 

Fees and Other Direct and Indirect Payments Made by the Depositary to Us

 

Our Depositary has agreed to reimburse us for certain expenses we incur that are related to establishment and maintenance of the ADR program, including investor relations expenses and exchange application and listing fees. In 2013, the Depositary did not make reimbursements to us. In 2014, reimbursements were made in the amount of approximately US$3,093,346 for expenses related to investor relations activities. In 2015, reimbursements were made in the amount of approximately US$2,069,202 for expenses related to investor relations activities.

 

6.5Taxation

 

6.5.1Colombian Tax Considerations

 

The following is a general description of the Colombian tax considerations for investments in common shares in Colombia or for the purchase of ADSs, in a foreign securities market. This description is based on applicable law in effect as of the date of this annual report is issued, which may be subject to changes.

 

Prospective purchasers of common shares or ADSs should consult their own tax advisors for a detailed analysis of the tax consequences in Colombia, resulting from the acquisition, ownership and disposition of common shares or ADSs.

 

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General Rules

 

Colombian entities and individuals who are deemed to be residents within the Colombian national territory for Colombian tax purposes are subject to Colombian income tax on their worldwide income. Foreign entities and individuals, as well as their permanent establishments in Colombia, who are not deemed to be residents in Colombia for tax purposes are subject to income tax in Colombia only with respect to their national-source income, which is generally defined as income obtained from (i) the rendering of services inside Colombian territory, (ii) the exploitation of tangible and intangible assets in Colombia, and (iii) the sale of tangible or intangible assets that are located inside Colombian territory at the time of title passage. Double taxation treaties signed by Colombia, if applicable, may provide for special regulations regarding income tax. Dividends paid by Colombian companies are deemed Colombian income. However, they will only be subject to tax in Colombia if paid out of non-taxed earnings. In the event that dividends are paid out of non-taxed earnings, the applicable withholding tax is typically 33%. Relief or reduced tax rates may apply under an applicable treaty to avoid double taxation. An additional tax on dividends may be created by means of a tax reform that may be submitted for analysis with the Colombian Congress in 2016. The exact rate and features of this dividend tax are unknown, but if passed it will likely apply to all dividend distributions regardless of whether dividends are distributed from taxed or non-taxed earnings. Certain double taxation treaties may provide for relief or protection with respect to the dividend tax, but a specific analysis will be required once the new tax is in effect.

 

For Colombian tax purposes, an individual is considered to be a Colombian resident when he/she meets any of the following criteria:

 

(1)He/she remains in Colombia continuously or discontinuously for more than 183 calendar days within any given 365-consecutive-day term;

 

(2)He/she is related to the Colombian government’s foreign service or to individuals who are in the Colombian government’s foreign service and who, by virtue of the Vienna Conventions on diplomatic and consular relations, are exempted from taxes during the time of their service; or

 

(3)He/she is a Colombian national and:

 

-Has a spouse or permanent companion, or dependent children, who are tax residents in Colombia, or

 

-50% or more of his or her total income is Colombian source income, or

 

-50% or more of his or her assets are managed in Colombia, or

 

-50% or more of his or her assets are deemed to be located or possessed in Colombia, or

 

-Has failed to provide proof of residency in another country (different from Colombia) upon previous official request by the Colombian tax office, or

 

-He/she has a tax residency in a country considered by the Colombian government to be a low tax jurisdiction or a tax haven.

 

Law 1739 of 2014 clarifies that Colombian nationals who meet any of the following requirements, will not be deemed as tax residents:

 

-If more than 50% of his or her annual income, has its source in the jurisdiction where he or she is domiciled and whose country of domicile is not Colombia.

 

-If more than 50% of his/her assets are located in the jurisdiction where he or she is domiciled and whose country of domicile is not Colombia.

 

For purposes of Colombian taxation, an entity is deemed to be a “national” or a “Colombian entity” and, therefore, subject to taxation in Colombia on its worldwide income, if it meets any of the following criteria:

 

(1)It has its place of effective management, in Colombia during the corresponding year or taxable period;

 

(2)It has its main domicile in the Colombian territory; or

 

(3)It has been incorporated in Colombia, in accordance with Colombian laws.

 

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Pursuant to the Colombian Tax Statute, a foreign company or non-resident individual has a permanent establishment in Colombia when said company or individual performs activities in Colombia through: (1) a fixed place of business (i.e., branches, factories or offices), or (2) an individual who is not an independent agent empowered to execute agreements on behalf of the foreign company. As noted above, permanent establishments are considered Colombian taxpayers in connection with the Colombian-source income and Colombian-source taxable gains attributed to said permanent establishment. A foreign company or entity will not be deemed to have a permanent establishment by the sole fact that it acts through a broker or any other independent agent. In addition, passive-income generating activities, such as dividends, royalties and interests, typically do not qualify as entrepreneurial and are not deemed to create permanent establishments.

 

Tax Treatment of a Non-Colombian Entity and a Non-Resident Individual of Colombia Who Purchases an ADS in a Foreign Securities Market

 

Dividends

 

As a general rule, dividends paid to foreign companies, foreign entities or non-resident individuals who are investing in ADSs which underlying assets are Colombian shares are treated as Colombian-source income and are thus subject to Colombian income tax.

 

To avoid double taxation, dividends paid by Colombian entities are not subject to income tax at the shareholder level when they are paid out of corporate profits that have been previously taxed at the corporate level. However, the Colombian government is analyzing the possibility of creating a new dividend tax that may apply to all dividend distributions regardless of whether they are paid out of taxed or non-taxed earnings.

 

In light of the above, the applicable withholding tax rate for an entity or a non-resident individual investing through a Foreign Funds Administration Account (FFAA) is 25%, since its investment qualifies as portfolio investments and the dividends that are distributed by the Colombian entity are not taxed at the corporate level (assuming that the dividends cannot be attributed to a permanent establishment in Colombia belonging to the shareholder). These foreign shareholders subject to this withholding tax are not required to file an income tax return in Colombia.

 

Taxation of Capital Gains from the Sale of ADSs

 

Capital gains obtained from the sale of ADSs by non-Colombian entities, Colombian individuals who are non-residents in Colombia and foreign non-resident individuals, are not subject to income tax in Colombia as such sale does not generate Colombian-source income to the extent that the ADSs are not deemed to be possessed in Colombia.

 

If the holder of the ADSs who is a non-resident entity, a Colombian individual who is not a resident in Colombia or a foreign non-resident individual, decides to surrender the ADSs and withdraw the underlying common shares, it is arguable that such transaction does not generate a capital gain subject to income tax in Colombia. However, different interpretations may be adopted by the Colombian Tax Authorities on this matter.

 

Tax Treatment in Colombia of a Non-Colombian Entity and a Non-Resident Individual of Colombia Who Purchases Ecopetrol’s Shares in Colombia’s Securities Market

 

Dividends

 

As a general rule, dividends paid to foreign companies, foreign entities, or to non-resident individuals in Colombia, who are investing in Colombian shares directly or through a FFAA, are treated as national-source income; thus, they are subject to Colombian income tax.

 

To avoid double taxation, dividends are not subject to income tax at the shareholder level when they are paid out of corporate profits that have been previously taxed at the corporate level.

 

If the shareholder is a non-resident entity or a non-resident individual investing directly, it will be taxed upon distribution, by means of the withholding tax mechanism, provided that its investment does not qualify as portfolio investments and dividends that are distributed are not taxed at the corporate level. In this case, dividends will be subject to a 33% withholding tax.

 

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Non-resident entities or non-resident individuals will be taxed upon distribution by means of the withholding tax mechanism, provided that their investments qualify as portfolio investments (i.e., investing through a FFAA and dividends that are distributed by the Colombian entity are not taxed at the corporate level. In this case, the applicable withholding tax rate is 25%, assuming that the dividends cannot be attributed to a permanent establishment in Colombia belonging to the shareholder). These foreign shareholders subject to this withholding tax are not required to file an income tax return in Colombia.

 

Taxation of Capital Gains for the Sale of Shares

 

Capital gains derived from the sale of shares listed on the BVC and owned by the same beneficial owner, are deemed as non-taxable income in Colombia, provided that the shares sold during the same taxable year do not represent more than 10% of the outstanding shares of the listed company. Pursuant to Article 18 of Decree 2634 of 2012, sellers of shares are not required to file an income tax return for the transfer of securities that are listed in the National Registry of Securities and Issuers (Registro Nacional de Valores y Emisores) as long as the foreign investment is treated as a portfolio investment according to article 3 of Decree 2080 of 2000.

 

If the above-mentioned requirements are not met, the capital gain obtained in the sale of shares is subject to income tax or capital gains tax, under the following rules:

 

·The gain or loss arising therefrom will be the difference between the sale price and the tax basis of the shares. As a general rule, the tax basis of shares is equal to the price paid for such shares (i.e., cost of acquisition).

 

·The applicable tax rate and the withholding tax rate have to be determined on a case-by-case basis. Generally, if the shares have been owned for at least two years, the profits from the sale will qualify as capital gains taxable at 10%, otherwise, profits will qualify as ordinary income taxable at 40% in 2016 (42% in 2017 and 43% in 2018).

 

Tax Treatment of Non-Residents Who Purchase Ecopetrol’s Shares in the BVC Market and Exchange Them for ADSs

 

Dividends

 

Payment of dividends by Colombian entities to foreign companies, foreign entities or to non-resident individuals who are investing in ADSs which underlying assets are Colombian shares or in Colombian shares directly are subject to the tax treatment described above.

 

Taxation on Capital Gains for the Sale of Shares

 

If the holder of the Colombian shares is a non-resident entity, a Colombian individual who is not a resident in Colombia or a foreign non-resident individual, and such holder decides to exchange such common shares for ADSs, it is arguable that such transaction should not generate a capital gain subject to income tax in Colombia. However, different interpretations may be adopted by the Colombian tax authorities on this matter. For instance, assuming that the exchange of securities is treated as a sale of Ecopetrol’s shares, the seller would be subject to the tax treatment described above in connection with the taxation of capital gains for the sale of shares. Absent any specific rules or regulations addressing this specific situation, a case-by-case analysis would be necessary.

 

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6.5.2U.S. Federal Income Tax Consequences

 

This summary describes the principal U.S. federal income tax consequences of the ownership and disposition of common shares or ADSs, but it does not purport to be a comprehensive description of all of the U.S. tax consequences that may be relevant to a decision to hold or dispose of common shares or ADSs. This summary applies only to purchasers of common shares or ADSs who will hold the common shares or ADSs as capital assets for U.S. federal income tax purposes and does not apply to special classes of holders such as dealers in securities or currencies, holders whose functional currency is not the U.S. dollar, holders of ten percent or more of our shares (taking into account shares held directly or through depositary arrangements), tax-exempt organizations, financial institutions, holders liable for the alternative minimum tax, securities traders who elect to account for their investment in common shares or ADSs on a mark-to-market basis, partnerships or other pass-through entities, insurance companies, U.S. expatriates, persons that purchase or sell common shares or ADSs as part of a wash sale for tax purposes, and persons holding common shares or ADSs in a hedging transaction or as part of a straddle, conversion or other integrated transaction for U.S. federal income tax purposes. The statements regarding U.S. tax law set forth in this summary is based on the Internal Revenue Code of 1986, as amended, which we call the “Code,” its legislative history, existing and proposed U.S. Treasury regulations, published rulings and court decisions all as in force on the date of this annual report, and changes to such law subsequent to the date of this annual report may affect the tax consequences described herein (possibly with retroactive effect). This summary is also based in part on the representations of the Depositary and the assumption that each obligation in the Deposit Agreement and any related agreement will be performed in accordance with its terms.

 

Each holder is encouraged to consult such holder’s tax advisor concerning the overall tax consequences to it, including the consequences under laws other than U.S. federal income tax laws, of an investment in common shares or ADSs.

 

In this discussion, references to a “U.S. Holder” are to a beneficial holder of a common share or an ADS that is for U.S. federal income tax purposes (1) an individual citizen or resident of the United States, (2) a corporation, or any other entity taxable as a corporation, organized under the laws of the United States, any state thereof or the District of Columbia, (3) an estate whose income is subject to U.S. federal income tax regardless of its source, or (4) a trust if (i) a United States court can exercise primary supervision over the trust’s administration and one or more United States persons are authorized to control all substantial decisions of the trust or (ii) it has in effect a valid election under applicable U.S. Treasury regulations to be treated as a U.S. person.

 

For U.S. federal income tax purposes, holders of ADSs will generally be treated as owners of the common shares represented by such ADSs.

 

This discussion does not address any aspect of U.S. federal taxation other than U.S. federal income taxation (such as the estate and gift tax or the Medicare tax on net investment income). Holders of common shares or ADSs should consult their own tax advisor regarding the U.S. federal, state and local and other tax consequences of owning and disposing of common shares and ADSs in their particular circumstances.

 

Distributions on Common Shares or ADSs

 

A distribution to U.S. Holders made by us of cash or property with respect to common shares or ADSs generally will be treated as a dividend for U.S. federal income tax purposes to the extent paid out of our current or accumulated earnings and profits (as determined under U.S. federal income tax principles). Distributions in excess of our current or accumulated earnings and profits, as determined for U.S. federal income tax purposes, will be treated first as a tax-free return of capital reducing such U.S. Holder’s adjusted tax basis in the common shares or ADSs. Any distribution in excess of such adjusted tax basis will be treated as capital gain and will be either long-term or short-term capital gain depending upon whether the U.S. Holder held the common shares or ADSs for more than one year. Distributions of additional common shares or ADSs to U.S. Holders that are part of a pro rata distribution to all of our shareholders generally will not be subject to U.S. federal income tax. We do not maintain calculations of our earnings and profits under U.S. federal income tax principles, and, therefore, U.S. Holders should expect that any distributions generally will be reported as dividends for U.S. federal income tax purposes. As used below, the term “dividend” means a distribution that constitutes a dividend for U.S. federal income tax purposes.

 

The amount of any distribution will include the amount of any Colombian tax withheld on the amount distributed, and the amount of a distribution paid in Colombian Pesos will be measured by reference to the exchange rate for converting Colombian Pesos into U.S. dollars in effect on the date the distribution is received by the Depositary (or by a U.S. Holder in the case of a holder of common shares) regardless of whether the payment is in fact converted into U.S. dollars. If the Depositary (or U.S. Holder in the case of a holder of common shares) does not convert such Colombian Pesos into U.S. dollars on the date it receives them, generally, any gain or loss resulting from currency exchange fluctuations during the period from the date the dividend payment is included in income to the date the payment is converted into U.S. dollars will be treated as ordinary income or loss and will not be eligible for the special tax rate applicable to qualified dividend income (as discussed below). The gain or loss generally will be income or loss from sources within the United States for foreign tax credit limitation purposes. Dividends paid by us will not be eligible for the dividends received deduction allowed to corporations under the Code.

 

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If you are a non-corporate U.S. Holder, dividends that constitute qualified dividend income will be taxable to you at the preferential rates applicable to long-term capital gains provided that you meet certain holding requirements. Dividends paid on the ADSs will be treated as qualified dividend income if (1) the ADSs are readily tradable on an established securities market in the United States and (2) we were not, in the year prior to the year in which the dividend was paid, and are not, in the year in which the dividend is paid, a passive foreign investment company (PFIC). The ADSs are listed on the New York Stock Exchange, and will qualify as readily tradable on an established securities market in the United States so long as they are so listed. Based on our audited financial statements and relevant market and shareholder data, we believe that we were not treated as a PFIC for U.S. federal income tax purposes with respect to our 2015 taxable year. In addition, based on our audited financial statements and our current expectations regarding the value and nature of our assets, the sources and nature of our income, and relevant market and shareholder data, we do not anticipate becoming a PFIC for the 2016 taxable year. However, this conclusion is a factual determination that is made annually and thus may be subject to change. Based on existing guidance, it is not clear whether dividends received with respect to the common shares will be treated as qualified dividends. In addition, the U.S. Treasury has announced its intention to promulgate rules pursuant to which holders of ADSs or common shares and intermediaries through whom such securities are held will be permitted to rely on certifications from issuers to treat dividends as qualified for tax reporting purposes. Because such procedures have not yet been issued, it is not clear whether we will be able to comply with them. Holders of ADSs and common shares should consult their own tax advisers regarding the availability of the reduced dividend tax rate in the light of the considerations discussed above and their own particular circumstances.

 

A U.S. Holder will be entitled, subject to a number of complex limitations and conditions, to claim a U.S. foreign tax credit in respect of any Colombian income taxes withheld on dividends received on common shares or ADSs. U.S. Holders who do not elect to claim a credit for any foreign income taxes paid during the taxable year may instead claim a deduction in respect of such Colombian income taxes provided the U.S. Holder elects to deduct (rather than credit) all foreign income taxes for that year. Dividends received with respect to the common shares or ADSs will be treated as foreign source income, subject to various classifications and other limitations. For the purposes of the U.S. foreign tax credit limitations, the dividends paid with respect to our common shares or ADSs will generally constitute “passive category income” for most U.S. Holders. The rules relating to computing foreign tax credits or deducting foreign income taxes are extremely complex, and U.S. Holders are urged to consult their own independent tax advisers regarding the availability of foreign tax credits with respect to any Colombian income taxes withheld.

 

Sale, Exchange or Other Taxable Dispositions of Common Shares or ADSs

 

A U.S. Holder generally will recognize capital gain or loss upon the sale, exchange or other taxable disposition of common shares or ADSs in an amount equal to the difference between the U.S. dollar value of the amount realized on the sale, exchange or other taxable disposition of the common shares or ADSs and the U.S. Holder’s adjusted tax basis, determined in U.S. dollars, in the common shares or ADSs. Any gain or loss will be long-term capital gain or loss if the common shares or ADSs have been held for more than one year. Certain non-corporate U.S. Holders (including individuals) may be eligible for preferential rates of U.S. federal income tax in respect of long-term capital gains. The deductibility of capital losses is subject to limitations under the Code.

 

If you are a U.S. Holder of common shares or ADSs, the initial tax basis of your common shares or ADSs will be the U.S. dollar value of the Colombian Peso-denominated purchase price determined on the date of purchase. If the common shares or ADSs are treated as traded on an “established securities market,” a cash basis U.S. Holder, or, if it elects, an accrual basis U.S. Holder, will determine the dollar value of the cost of such common shares or ADSs by translating the amount paid at the spot rate of exchange on the settlement date of the purchase. Such an election by an accrual basis U.S. Holder must be applied consistently from year to year and cannot be revoked without the consent of the Internal Revenue Service (“IRS”). If you convert U.S. dollars to Colombian Pesos and immediately use that currency to purchase common shares or ADSs, such conversion generally will not result in taxable gain or loss to you.

 

With respect to the sale or exchange of common shares or ADSs, the amount realized generally will be the U.S. dollar value of the payment received determined on (1) the date of receipt of payment in the case of a cash basis U.S. Holder and (2) the date of disposition in the case of an accrual basis U.S. Holder. If the common shares or ADSs are treated as traded on an “established securities market,” a cash basis taxpayer, or, if it elects, an accrual basis taxpayer, will determine the U.S. dollar value of the amount realized by translating the amount received at the spot rate of exchange on the settlement date of the sale.

 

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Deposits and withdrawals of common shares in exchange for ADSs, and ADSs for common shares generally will not result in the realization of gain or loss for U.S. federal income tax purposes.

 

Backup Withholding and Information Reporting

 

In general, dividends on common shares or ADSs, and payments of the proceeds of a sale, exchange or other taxable disposition of common shares or ADSs, paid within the United States, by a U.S. payor through certain U.S.-related financial intermediaries to a U.S. Holder are subject to information reporting and may be subject to backup withholding at a current rate of 28% unless the holder (1) establishes that it is a corporation or other exempt recipient or (2) with respect to backup withholding, provides an accurate taxpayer identification number and certifies that it is a U.S. person and that no loss of exemption from backup withholding has occurred.

 

Backup withholding is not an additional tax. The amount of any backup withholding tax from a payment to a U.S. Holder will be allowed as a credit against the U.S. Holder’s U.S. federal income tax liability, provided that the required information is timely furnished to the IRS. A U.S. Holder generally may obtain a refund of any amounts withheld under the backup withholding rules that exceed its U.S. federal income tax liability by timely filing a refund claim with the IRS.

 

U.S. Tax Considerations for Non-U.S. Holders

 

A holder or beneficial owner of common shares or ADSs that is not a U.S. Holder for U.S. federal income tax purposes (a “non-U.S. Holder”) generally will not be subject to U.S. federal income or withholding tax on dividends received on common shares or ADSs, unless the dividends are “effectively connected” with the non-U.S. Holder’s conduct of a trade or business within the United States. In such a case a non-U.S. Holder generally will be taxed in the same manner as a U.S. Holder. In the case of “effectively connected” dividends received by a corporate non-U.S. Holder, the corporate non-U.S. Holder may, under certain circumstances, be subject to an additional “branch profits tax” at a 30% rate.

 

A non-U.S. Holder of common shares or ADSs will not be subject to U.S. federal income or withholding tax on gain realized on the sale of common shares or ADSs, unless (i) the gain is “effectively connected” with the non-U.S. Holder’s conduct of a trade or business in the United States, or (ii) in the case of gain realized by an individual non-U.S. Holder, the non-U.S. Holder is present in the United States for 183 days or more in the taxable year of the sale and certain other conditions are met. In the case of “effectively connected” gains realized by a corporate non-U.S. Holder, the corporate non-U.S. Holder may, under certain circumstances, be subject to an additional “branch profits tax” at a 30% rate.

 

Although non-U.S. Holders generally are exempt from backup withholding and information reporting requirements, a non-U.S. Holder may be required to comply with certification and identification procedures in order to establish its exemption from information reporting and backup withholding.

 

6.6Exchange Controls and Limitations

 

Payments in foreign currency with respect to certain foreign exchange transactions including international investments between Colombian residents and non-Colombian residents must be conducted through the foreign exchange market. Therefore, any foreign currency income or expense under the ADRs must be completed through the appropriate channels of the foreign exchange market. Transactions conducted through the foreign exchange market are made at market rates freely negotiated with authorized foreign exchange intermediaries (local banks, financial corporations, administrators and others). As of September 25, 1999 the Colombian foreign exchange regime is structured under the system of free flotation of the exchange rate whereby market forces determine the level of exchange rate from time to time.

 

Foreign portfolio investments must be made through authorized foreign exchange investment management companies. Only brokerage firms, trust companies and investment management companies, subject to the inspection and supervision of the Superintendency of Finance, are allowed to make investments in the local Colombian market on behalf of foreign investors. Such brokerage firms, trust companies and investment management companies also act as the foreign investors’ local representatives for tax and foreign exchange purposes.

 

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Colombian law provides that the Colombian Central Bank may intervene in the foreign exchange market at its own discretion at any time (i.e. it may limit the remittance of dividends whenever the international reserves fall below an amount equal to three months of imports). Additionally, from time to time, the Colombian government introduces amendments to the International Investment Statute. Hence, we cannot assure you that the Colombian Central Bank will not intervene in the future imposing restrictions to the free convertibility system currently applicable in Colombia. See the section Risk Review—Risk Factors—Risks Related to Colombia’s Political and Regional Environment.

 

Registration of Foreign Investment Represented in Underlying Shares

 

Colombia’s International Investment Statute and the regulations issued by the Colombian Central Bank, which have been amended from time to time through related decrees and regulations, govern the manner in which non-Colombian resident entities and individuals can invest in Colombia and participate in the Colombian securities markets. Among other requirements, the International Investment Statute and Colombian Central Bank regulations mandate registration of foreign investment transactions with the Colombian Central Bank and specify procedures to authorize and administer such foreign investment transactions. Additionally, pertinent information related to foreign investment transactions must be updated on a regular basis (yearly or monthly, depending on the type of information).

 

Under the International Investment Statute and Colombian Central Bank regulations, the failure of a foreign investor to report or register with the Colombian Central Bank foreign exchange transactions relating to investments in Colombia on a timely basis may (i) prevent the investor from obtaining remittance rights, (ii) constitute an exchange control infraction, and (iii) result in financial sanctions.

 

Notwithstanding the regulations described above, foreign investors who acquire ADRs are not required to register this investment with Colombian authorities. Holders of ADRs will benefit from the registration to be obtained by the local custodian for our common shares underlying the ADRs in Colombia. Such registration allows the custodian to convert dividends and other distributions with respect to the common shares into foreign currency and remit the proceeds abroad. If investors in ADRs choose to surrender their ADRs and withdraw common shares, they must retain an administrator, who will act as a local representative for the investments, and register their investments in common shares as a portfolio investment through said local representative. The local representative is the brokerage firm, trust company or investment management company that acts on behalf of the holders of the ADRs in Colombia, and the request for registration is made by them.

 

Colombian residents who acquire ADRs and either receive profits from this investment, surrender their ADRs or liquidate their investment in ADRs must register these operations with the Colombian authorities and comply with applicable regulations through its Colombian brokerage firm.

 

In obtaining its own foreign investment registration, an investor who surrenders its ADRs and sells common shares may incur expenses and/or suffer delays in the application process. Investors would only be allowed to transfer dividends abroad or transfer funds received as distributions relating to our common shares after their foreign investment registration procedure with the Colombian Central Bank has been completed. In addition, the depositary’s foreign investment registration may also be adversely affected by future legislative changes, but its rights to transfer dividends abroad or profits arising from distributions relating to our common shares must be maintained according to Colombian law and foreign investment treaties entered into by Colombia in force at the time of the registration of the investment, except when Colombia’s international reserves fall below an amount equivalent to three months’ worth of imports. Prospective purchasers of common shares or ADSs should consult their own foreign exchange advisors.

 

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6.7Exchange Rates

 

On April 22, 2016, the Representative Market Exchange Rate was COP$2,928.70 per US$1.00. The Federal Reserve Bank of New York does not report a noon-buying rate for Colombian Pesos. The Superintendencia Financiera, or Superintendency of Finance, calculates the Representative Market Exchange Rate based on the weighted averages of the buy and sell foreign exchange rates quoted daily by foreign exchange rate market intermediaries including financial institutions for the purchase and sale of U.S. dollars. The Superintendency of Finance also calculates the Representative Market Exchange Rate for each month for purposes of preparing financial statements and converting amounts in foreign currency to Colombian Pesos.

 

The following table sets forth the high, low, average and period-end exchange rate for Colombian Peso/U.S. dollar Representative Market Exchange Rate for each of the last five years and for the last six months.

 

Table 63 – Colombian Peso/U.S. dollar Representative Market Exchange Rate

 

   Exchange Rates 
   High   Low   Average   Period-End 
2011   1,972.76    1,748.41    1,848.17    1,942.70 
2012   1,942.70    1,754.89    1,798.23    1,768.23 
2013   1,952.11    1,758.45    1,868.90    1,926.83 
2014   2,446.35    1,846.12    2,000.68    2,392.46 
2015   3,356.00    2,360.58    2,743.39    3,149.47 
October   3,086.75    2,855.74    2,929.47    2,921.32 
November   3,108.70    2,819.63    3,001.38    3,101.10 
December   3,356.00    3,131.95    3,244.20    3,149.47 
2016:                    
January   3,375.80    3,149.47    3,270.20    3,287.31 
February   3,434.89    3,287.31    3,354.96    3,306.00 
March   3,319.80    3,022.35    3,128.79    3,022.35 
April (through April 22, 2016)   3,109.60    2,899.92    3,023.87    2,928.70 

 

 

Source: Superintendency of Finance for historical data. Banco de la República, or the Colombian Central Bank, for averages.

 

6.8Major Shareholders

 

Major Shareholders

 

The following table sets forth the names of our major shareholders, and the number of shares and the percentage of outstanding shares owned by them at March 31, 2016:

 

Table 64 – Major Shareholders

 

   At March 31, 2016 
Shareholders  Number of shares   % Ownership 
Nation(1) – Ministry of Finance and Public Credit   36,384,788,817    88.49 
Public float   4,731,905,873    11.51 
Total   41,116,694,690    100 

 

 

(1)Includes 2,000 shares owned by other state entities.

 

All our common shares have identical voting rights.

 

As of March 31, 2016, 2.15% of our common shares were held of record in the form of American Depository Shares. As of March 31, 2016, we had 42 registered holders and as of February 19, 2016 we had 12,104 beneficiaries of common shares, or ADSs representing common shares, in the United States.

 

Changes in the Capital of the Company

 

There are no conditions in our bylaws governing changes in our capital stock that are more stringent than those required under Colombian law, with the exception that the Nation must hold a minimum of 80% of our capital stock at all times.

 

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6.9Enforcement of Civil Liabilities

 

We are a Colombian company. Most of our Directors and executive officers and some of the experts named in this annual report reside outside the United States. All or a substantial portion of our assets and the assets of these persons are located outside of the United States. As a result, it may not be possible for you to affect service of process within the United States upon us or these persons who are residents in Colombia or to enforce against us or these persons who are residents in Colombia judgments in U.S. courts obtained in such courts predicated upon the civil liability provisions of the U.S. federal securities laws. Colombian courts will enforce a U.S. judgment predicated on the U.S. securities laws through a procedural system known under Colombian Law as “exequatur.” The Colombian Supreme Court will enforce a foreign judgment, without reconsideration of the merits only if the judgment satisfies the requirements set forth in Articles 605 through 607 of Law 1564 of 2012 (Código General del Proceso) which entered into force on January 1, 2016, pursuant to Acuerdo No. PSAA15-10392, of October 1, 2015, issued by the Colombian Superior Council of the Judiciary (Consejo Superior de la Judicatura), as follows:

 

·A treaty exists between Colombia and the country where the judgment was granted relating to the recognition and enforcement of foreign judgments or, in the absence of such treaty, there is reciprocity in the recognition of foreign judgments between the courts of the relevant jurisdiction and the courts of Colombia;

 

·The foreign judgment does not relate to “in rem rights” vested in assets that were located in Colombia at the time the suit was filed;

 

·The foreign judgment does not contravene or conflict with Colombian laws relating to public order other than those governing judicial procedures;

 

·The foreign judgment, in accordance with the laws of the country where it was rendered, is final and is not subject to appeal;

 

·A duly legalized copy of the judgment (together with an official translation into Spanish if the judgment is issued in a foreign language) has been presented to the Supreme Court of Colombia;

 

·The foreign judgment does not refer to any matter upon which Colombian courts have exclusive jurisdiction;

 

·No proceeding is pending in Colombia with respect to the same cause of action, and no final judgment has been awarded in any proceeding in Colombia on the same subject matter and between the same parties;

 

·In the proceeding commenced in the foreign court that issued the judgment, the defendant is served in accordance with the laws of such jurisdiction and in a manner reasonably designated to give the defendant an opportunity to defend against the action; and

 

·The legal requirements pertaining to the exequatur proceedings have been observed;

 

The United States and Colombia do not have a bilateral treaty providing for automatic reciprocal recognition and enforcement of judgments in civil and commercial matters. The Colombian Supreme Court has in the past accepted that reciprocity exists when it has been proven that either a U.S. court has enforced a Colombian judgment or that a U.S. court would enforce a foreign judgment, including a judgment issued by a Colombian court. However, such enforceability decisions are considered by Colombian courts on a case-by-case basis.

 

Proceedings for enforcement of a money judgment by attachment or execution against any assets or property located in Colombia are within the exclusive jurisdiction of Colombian courts and such proceedings are conducted in Spanish. All parties affected by a foreign judgment in exequatur proceedings must be summoned to the exequatur proceedings in accordance with the rules that apply to the Colombian courts. In the course of such proceedings, both the plaintiff and the defendant are afforded the opportunity to request that evidence be collected in connection with the requirements listed above. In addition, before the judgment is rendered, each party may file final allegations in support of such party’s position regarding the above-mentioned requirements.

 

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Assuming that a foreign judgment complies with the standards set forth in the preceding paragraphs and the absence of any condition referred to above that would render a foreign judgment not subject to recognition under Colombian law, such foreign judgment would be enforceable in Colombia in an enforcement proceeding under the laws of Colombia, provided that the Colombian Supreme Court has previously granted exequatur upon the foreign judgment.

 

7.Corporate Governance

 

Since 2004, Ecopetrol S.A. has voluntarily adopted transparency, governance and control practices to facilitate corporate governance in order to generate confidence among stakeholders and ensure the sustainability of its business.

 

The corporate governance practices at Ecopetrol S.A.:

 

·Promote and guarantee all stakeholders transparency, objectivity and competiveness.

 

·Add value to the company and attract investors.

 

·Protect shareholders, investors and stakeholders rights.

 

·Encourage financial markets confidence.

 

·Accomplish the highest corporate governance standards.

 

Statement of the Nation as Majority Shareholder

 

Ecopetrol’s majority shareholder (the Nation, represented by the Ministry of Finance and Public Credit), is unilaterally committed to protect the interests of the minority shareholders in the following topics:

 

·Composition of Board of Directors: including in its list of candidates a Representative for hydrocarbon producing departments operated by Ecopetrol and a Representative for the minority shareholders, who will be chosen by the 10 shareholders with the largest stock participations.

 

According to corporate governance practices recommended by the OECD, organization to which Colombia is in the process of access, the National Government begun to implement the practice of reducing the participation of Directors with a ministerial level in Ecopetrol’s Board of Directors. Thus, in 2017 in the ordinary Shareholders’ Assembly, the National Government will nominate only one (1) non-independent Director with a ministerial level and in 2018 no director of ministerial rank will be nominated.

 

·Dividend policy: guaranteeing the right of each shareholder to receive his pro rata dividends in accordance with Colombian law.

 

·Issues not included in the agenda of extraordinary meetings of the Shareholders Assembly: permitting a vote on those initiatives submitted by one or more shareholders representing at least 2% of the subscribed shares of the company.

 

·Asset disposal: ensuring that any asset disposal of an amount equal or higher than 15% of the stock exchange capitalization of Ecopetrol is discussed and decided by the Shareholders’ General Assembly and that the Nation will only vote affirmatively if the vote of minority shareholders is equal to or exceeds 2% of the shares subscribed by shareholders other than the Nation.

 

7.1Bylaws

 

The Bylaws of Ecopetrol S.A. are contained in Public Deed No. 5314 of December 14, 2007, issued by the Second Notary of Bogotá; amended by Public Deed No. 560 of May 23, 2011, issued by the Notary Forty- Six of Bogotá, Deed No. 666 of May 7, 2013, issued by the Notary Sixty-Five of Bogotá, and Deed No. 1049 of May 19, 2015, issued by the Notary Second of Bogotá.

 

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This summary does not purport to be complete and is qualified by reference to our bylaws, which are filed as an exhibit to this annual report. For a description of the provisions of our bylaws relating to our Board of Directors and its committees, see the sections Corporate Governance—Board of Directors—Board Practices and —Board Committees.

 

On March 26, 2015, the Shareholders’ General Assembly approved the following amendments to our bylaws:

 

1.The adoption of the following corporate governance practices recommended by the Superintendency of Finance regarding the New Code of Corporate Best Practices of Colombia:

 

·Extension of the deadline for convening ordinary and extraordinary meetings (amendment to Articles 19 and 20).

 

·The majority of the Board of Directors will be constituted by independent members (amendment to paragraph 1, Article 23).

 

·Possibility of performing different kind of evaluations of the Board of Directors (amendment to paragraph 5, Article 23).

 

·Reference to certain guidelines concerning the appointment and duties of the Chairman and Secretary of the Board of Directors (new paragraph 6, Article 23).

 

·Modification in the name of the audit and risk committee of the Board of Directors in order to make explicit its risk management role (amendment to Paragraph 27.1 of Article 27).

 

·Obligation to comply with voluntarily adopted corporate governance practices (new Article 52).

 

2.The company’s reserves accounts amounting to COP$14.76 trillion in the financial statements as of December 31, 2014 were capitalized by increasing the nominal value of shares from COP$250 to COP$609 per share.

 

General Meeting of Shareholders

 

Shareholders’ meetings may be ordinary or extraordinary. Ordinary meetings will take place in our legal domicile located in Bogota, Colombia, within the first three months following the end of each fiscal year, on the day and at the time set forth in the notice for the general shareholders’ meeting. The call for the general shareholders’ meeting is published on the Ecopetrol S.A. website and in a newspaper of wide circulation 30 calendar days prior to the date on which the meeting will take place and on the Sunday previous to the meeting, must be published at Ecopetrol S.A.’s website www.ecopetrol.com.co. The call for the general shareholders’ meeting is also sent electronically to shareholders.

 

In the ordinary general shareholders’ meeting, our Board of Directors and the external auditor are appointed and our annual financial statements, profit distribution, audit and management reports, including our corporate governance report and sustainability report, and any other matter provided under applicable law or our corporate bylaws are approved.

 

Extraordinary meetings of shareholders may be called by our Board of Directors, by our president or chief executive officer, by our external auditor, or by shareholders holding at least 5% of the shares outstanding, or when unforeseen or urgent needs of the Company require it. Calls to extraordinary meetings should be made at least 15 calendar days prior to the date of the meeting, with the exception of the case where the Law requires a greater time between the summons and the meeting. Such a call is published on the Ecopetrol S.A. website and in a newspaper of wide circulation. The meeting notice must specify the agenda for the meeting.

 

The required quorum for both ordinary and extraordinary meetings is a plural number of shareholders representing 50% plus one of the subscribed shares entitled to vote and decisions are approved with a majority of the members present. This quorum is exempted in the case of “second-call meetings,” which may take place when a meeting fails to obtain the required quorum and is called within a period between 10 business days and 30 business days from the first date, in which case decisions may be adopted by a majority of the shares present regardless of the number represented.

 

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Decisions made at ordinary and extraordinary shareholders’ meeting must be approved by a plural number of shareholders representing the majority of the shares present. Colombian law requires supermajorities in the following cases:

 

·The vote of at least 70% of the shares present and entitled to vote at the ordinary shareholders’ meeting is required to approve the issuance of stock not subject to preemptive rights;

 

·The vote of at least 78% of the shares represented entitled to vote is required to approve the distribution of the annual net profits. In the absence of this special majority, at least 50% of the net profits must be distributed. If the sum of all legal reserves (statutory, legal and optional) exceeds the amount of the outstanding capital, the Company must distribute at least 70% of the annual net profits;

 

·The vote of at least 80% of the shares represented is required to approve the payment of dividends in shares; and

 

·The vote of 100% of the outstanding and issued shares is required to replace a vacancy on the Board of Directors without applying the electoral quotient system.

 

Shareholders may be represented by proxies provided that the proxy: (1) is in writing (faxes and electronic documents are valid), (2) specifies the name of the representative, (3) specifies the date or time of the meeting for which the proxy is given and (4) includes other information specified by the applicable law. Proxies granted abroad do not require legalization or an apostille.

 

During our ordinary annual shareholders’ meeting, our employees and Directors are only allowed to represent their own shares, unless they act as legal representatives.

 

Preference Rights and Restrictions Attaching to Our Shares

 

We have only one class of stock without special rights or restrictions (ordinary shares). Our shareholders do not have any type of preemptive rights.

 

Under Commercial Colombian law, our shareholders have the following economic privileges and voting rights:

 

·To participate and vote on the decisions of the general shareholders’ meeting;

 

·To receive dividends based on the financial performance of the Company in proportion to their share ownership;

 

·To transfer and sell shares according to our bylaws and Colombian law;

 

·To inspect corporate books and records 15 business days prior to the ordinary shareholders’ meeting where the year-end financial statements are to be approved;

 

·Upon liquidation, to receive a proportional amount of the corporate assets after the payment of external liabilities; and

 

·To sell the shares, known as derecho de retiro, if a corporate restructuring affects the economic or voting rights of the shareholders in the terms and conditions established under Colombian law.

 

Our bylaws and corporate governance code provide additional rights to our minority shareholders. These rights include:

 

·Sale of Assets. For a ten-year period counted from the date of subscription of the declaration of the Nation dated July 26, 2007 or until the Nation loses its status as majority shareholder, the Nation guarantees that any sale of 15% or more of our assets requires the approval of the general shareholders’ meeting and that the Nation would only be allowed to vote its shares in favor of the proposal if 2% or more of our minority shareholders accept the proposal.

 

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·Candidate List. Pursuant to our bylaws and Law 1118 of 2006, the Nation will include in its candidate list for election of members of the Board of Directors one member selected by the departments that produce hydrocarbons. In addition, pursuant to the declaration of the Nation dated July 26, 2007, the Nation will include in its candidate list for election of members of the Board of Directors one member selected by the ten largest minority shareholders. The minority shareholders’ right to select a candidate loses its effect when minority shareholders, according to their share participation, name a member to our Board of Directors.

 

·Extraordinary Meetings. Our bylaws and corporate governance code provide that the entity exercising permanent control over Ecopetrol must instruct the Company’s CEO or External Auditor to call an extraordinary meeting of the Company’s shareholders when so requested by a plurality of shareholders holding at least 5% of the total number of outstanding shares. Such requests shall be made in writing and must clearly indicate the purpose of the meeting.

 

·Investor Attention Office. Ecopetrol has an investor attention office, a specialized unit responsible for receiving complaints from our shareholders. Pursuant to our bylaws, shareholders holding at least 5% of the total number of shares outstanding may request that the investor attention office conduct a special audit of the following documents: the income statement; the proposal for the distribution of profits; the report of the Board of Directors as to the economic and financial status of our Company; the report from our general counsel as to the legal status of our Company; and the report from the independent auditors. Special audits cannot be made of documents that contain scientific, technological or statistical information of our Company, or agreement that gives us competitive and economic advantages over our competitors, or in respect of any document related to intellectual property. Shareholders also have the right to propose good corporate governance recommendations to the office for the protection of investors.

 

·Others. Pursuant to our bylaws, shareholders holding at least 5% of the total number of shares outstanding may propose recommendations to our Board of Directors pertaining to the management of our Company. Any shareholder may file a written petition to our Board of Directors to investigate corporate governance violations that the shareholder believes to have been committed.

 

Amendments to Rights and Restrictions to Shares

 

We have only one class of stock and it has no special rights or restrictions (ordinary shares). Our shareholders do not have any type of preemptive rights. The rights given to our shareholders by law are described in our bylaws and may only be modified through an amendment to the law.

 

The additional rights given to our minority shareholders in our bylaws and corporate governance code may only be modified through an amendment of those internal documents.

 

Limitations on the Rights to Hold Securities

 

There are no limitations in our bylaws or Colombian law on the rights of Colombian residents or foreign investors to own the shares of our Company, or on the right to hold or exercise voting rights with respect to those shares, except in cases of legal representation and except that the Nation must hold a minimum of 80% of our capital stock at all times.

 

Restrictions on Change of Control Mergers, Acquisitions or Corporate Restructuring of the Company

 

Under Colombian law and our bylaws, the general shareholders’ meeting has full authority to approve any corporate restructuring, including any mergers, acquisitions or spin-offs. Corporate restructurings are also subject to the requirement that the Nation must hold a minimum of 80% of our common stock at all times. So long as Law 1118 of 2006 is in effect, there cannot be any restructuring that results in a change of control of our Company.

 

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Ownership Threshold Requiring Public Disclosure

 

Our corporate governance code (Title III, chapter 1, Section 5, Identification of the Main Shareholders) provides that we must disclose periodically on our web page, the names of the shareholders of our Company including, at least, the 20 shareholders with the greatest number of shares. We must also disclose this information to the Superintendency of Finance at the end of each quarter.

 

Colombian securities regulations set forth the obligation to disclose any material event or hecho relevante. Any transfer of shares equal or greater than 5% of our capital stock or any person acquiring a percentage of shares that would make him the beneficial owner of 5% or more of our capital stock, is a material event, and therefore, must be disclosed to the Superintendency of Finance. The regulation includes other criteria in order to identify when to report a material event other than the situations described in the previous sentence.

 

External Auditor

 

Pursuant to our bylaws, our external auditor shall not be appointed for more than five consecutive one-year terms by us. However, an external auditor may be hired again after two terms have passed since the conclusion of its last term of appointment. At the ordinary general shareholders’ meeting on March 31, 2016, the shareholders appointed Ernst & Young Ltda. as external auditor of Ecopetrol.

 

7.2Code of Ethics

 

We have adopted a code of ethics, which complies with applicable U.S. and Colombian law.  Our code of ethics applies to our Board of Directors, our Chief Executive Officer, our Chief Financial Officer, principal accounting officer, persons performing similar functions and in general to all of the other employees of the company and its affiliates.

 

All of our agreements with suppliers or third parties include a provision relating to compliance with applicable anti-bribery and anti-corruption regulations. These agreements also require our suppliers and third parties to accept our Code of Ethics and our compliance manuals.

 

Our code of ethics is available on our website at http://www.ecopetrol.com.co/especiales/codigoEtica_/index.html.

 

If we amend the provisions of our code of ethics or if we grant any waiver of such provisions, we will disclose such amendment or waiver on our website at the same address.

 

7.3Board of Directors

 

The information below sets forth the names and business experience of each of our current Directors elected at the shareholders’ ordinary meeting held on March 31, 2016 for terms of one year beginning on that date, as of the date hereof:

 

Minister of Finance and Public Credit, Mauricio Cárdenas Santamaría (53) has been a member of our Board of Directors as a non-independent Director, appointed by the National Government, since March 27, 2008. Mr. Cárdenas is the Minister of Finance and Public Credit since September 2012. He was the Minister of Mines and Energy of Colombia from September 26, 2011 to September 3, 2012. He has served as Senior Fellow and Director at the Latin America Initiative of the Brookings Institution in Washington, D.C. Previously, Mr. Cárdenas served as Executive Director of Fedesarrollo (Fundación para la Educación Superior y el Desarrollo), President of Empresa de Energía Eléctrica de Bogotá, Minister of Economic Development, Minister of Transport and Director of the National Planning Agency of Colombia. Mr. Cárdenas holds a B.A. and an MSC in economics from the Universidad de los Andes and a Ph.D. in economics from the University of California, Berkeley. In 2001, Mr. Cárdenas was a visiting scholar at Harvard University’s Center for International Development. Mr. Cárdenas has also served as a member of the Board of Directors of various organizations, including the Latin American and Caribbean Economic Association, Universidad de los Andes and the BVC. Currently, he is a Director of the Colombian Central Bank.

 

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Director of the National Planning Agency of Colombia, Simón Gaviria Muñoz (35) has been a member of our Board of Directors since August 29, 2014 as a non-independent Director, appointed by the National Government. Mr. Gaviria is Director of the National Planning Agency since August, 2014. Before joining the National Planning Agency, Mr. Gaviria was the head of the Colombian Liberal Party. From 2006 and 2014 he served as representative to the Cámara de Representantes by Bogotá and from July 2011 and July 2012 he served as chairman of the Cámara de Representantes. During his early professional years he worked as a financial analyst at JP Morgan Chase Corporate Finance in New York. Mr. Gaviria is an economist from the University of Pennsylvania with a Master’s Degree in mathematics and econometrics from the same university.

 

Gustavo Adolfo Carvajal Sinisterra (54) has been a member of our Board of Directors as an independent Director since March 31, 2016. Mr. Carvajal was Ambassador of Colombia in France, as well as Non-Resident Ambassador in Monaco and Algeria and Ambassador to UNESCO from February 2011 to August 2013. He has held in various positions in the Carvajal Organization and has served as CEO of Grupo Editorial Norma. Mr. Carvajal holds a B.A. in economics and politics from the Adelphi University in New York and an MBA from Babson College in Boston. He is currently Chairman of the Board of Carvajal S.A. and a member of multiple boards of the Carvajal Organization. Mr. Carvajal is also a member of the Superior Council of the ICESI University, the Business Council of Latin America, the Board of Fedesarrollo, the Board of the Chamber of Commerce of Cali, the ANDI board and the Bolivar Group Board.

 

Jaime Ardila Gómez (60) has been a member of our Board of Directors as an independent Director since March 31, 2016. Mr. Ardila was president of General Motors for South America and has held various positions within General Motors, including in that company such as President for Brazil and Mercosur; Chief Financial Officer for Latin America, Africa and the Middle East; President and Managing Director in Argentina; COLMOTORES in Colombia and Ecuador; Omnibus BB, Chief Financial Officer in Chile; and Treasurer in Mexico, among others. He also served as Managing Director in Colombian Operations for N.M Rothschild and Sons and Secretary General of the Ministry of Industry and Trade in Colombia. Mr. Ardila holds a B.A. in economics from the University of Bogota Jorge Tadeo Lozano and a master´s degree in economics from the London School of Economics. Currently he is a member of the Board of Directors of Goldman Sachs BDC, Accenture, Council of the Americas and the Chamber of Commerce of Brazil.

 

Jorge Pinzón Sánchez (55) has been a member of our Board of Directors as an independent Director since December 6, 2012. He is a freelance attorney and an arbitrator registered at the Centers of Conciliation and Arbitration of the Chambers of Commerce of Bogotá and Barranquilla. He was a partner at Estudios Palacios Lleras S.A., a law firm specializing in consulting and arbitration of business, commercial and tax law. He also has served as the head of the Superintendency of Corporations as well as of the Superintendency of Finance of Colombia. He was also a member of the Advisory Committee of the Banking Superintendency, member of the General Board of the Securities Superintendency of Colombia, Secretary General of the Ministry of Finance and Public Credit and Deputy General Counsel, Secretary General and General Counsel of Banco del Comercio, among other positions in the public and private sector. He served several years as a Colombian representative to the United Nations Commission on International Trade Law. Mr. Pinzón holds a degree in law and a master’s degree in philosophy from Universidad Javeriana. Mr. Pinzón has been a member of several boards of directors of Colombian financial sector companies.

 

Joaquín Moreno Uribe (67) has been a member of our Board of Directors as an independent Director since March 27, 2008. Mr. Moreno worked for 33 years for the Royal Dutch/Shell Group. He has held various positions such as Project Manager in Colombia; Project and Operations Manager and Marketing and Operations Manager of Shell Química de Venezuela; Director of Marketing for Agrochemical Products and Global Marketing Manager for Petrochemical Products at Shell Centre–Shell International Chemicals Company in London; Director of Shell Venezuela S.A.; Director of Shell Colombia S.A., Director of Cerromatoso S.A., a Colombian mining company that is located in the department of Córdoba, dedicated to the production of ferro nickel and iron nickel alloy, and Exploration and Production Business Economics and Strategic Planning Director for Europe and the Middle East at the Shell International Headquarters in The Hague, the Netherlands. Mr. Moreno has also served as Country Chairman and President for Shell in Mexico, Colombia and Venezuela, as well as Regional CEO for Downstream Oil Business in the Northern Latin American Region. Mr. Moreno earned a degree in civil engineering from Universidad Industrial de Santander and completed a program in advanced management at Harvard University Business School. Mr. Moreno has been a member of the boards of directors of various local and international companies.

 

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Horacio Ferreira (46) has been a member of our Board of Directors as an independent Director, representing the hydrocarbon producing provinces of Colombia, since January 23, 2014. He is an executive leader with more than 20 years of international experience in the oil industry. His knowledge and expertise stem from previous positions as CEO and President of an oilfield services company in Houston, TX to application of state of art technologies in the oil industry. He has led and executed numerous reservoir engineering projects in the Americas, Europe, Africa, Middle East and Far East and has conducted research in optimization of multiphase meters, underbalanced reservoir engineering, real time reservoir and production analysis, reservoir simulation and waterflood techniques with horizontal wells. He holds a BS in Petroleum Engineering from Texas A&M University, master and doctoral degrees in Petroleum Engineering from Texas A&M University, and a business graduate degree in Management of International Corporations from Texas A&M University.

 

Roberto Steiner Sampedro (56) has been a member of our Board of Directors as an independent Director, representing the shareholders, since October 12, 2011. Mr. Steiner is an associate researcher and former Executive Director of Fedesarrollo. He served as Alternate Executive Director of the International Monetary Fund, Director of the Economics Research Department of the Colombian Central Bank, Director of the Economic Development Research Centre of Universidad de los Andes, Consultant at the World Bank, Deputy Director of Fedesarrollo, Deputy Director of the Economics Research Department of the Central Bank of Colombia, and Senior Economist at the Colombian Central Bank. He was a professor and researcher at various Colombian universities, including the Universidad de los Andes, Universidad Javeriana and Universidad Nacional. Also, he was a summer professor at Columbia University in New York. Mr. Steiner earned a degree in economics from Universidad de los Andes and master and doctoral degrees in economics from Columbia University in New York.

 

Carlos Alfredo Cure Cure (72) has been a member of our Board of Directors as an independent Director since September 5, 2015. Mr. Cure was Ambassador of Colombia in Venezuela and before becoming a diplomat, he was Chief Financial Officer and President of Bavaria S.A., the largest brewery in Colombia, and President of Avianca S.A., the national airline, and advisor to the Board of the Olympic Group S.A. He also served as deputy financial manager of Cementos del Caribe, CEO of Cementos Toluviejo and CEO of Shipyards Industrial Union. Mr. Cure holds a degree in Civil Engineering from the National University of Medellin. In addition, he has been a member of different boards of directors of Colombian companies. Currently is member of the board of directors of Isagen.

 

7.3.1Board Practices

 

Our Board of Directors is composed of nine members and is responsible for, among other things, establishing our general business policies. The majority of the Board of Directors must be independent, and must be elected pursuant to the criteria set out in paragraph two, Article 44, Law 964, 2005, and in accordance with the procedure determined in Decree 3923, 2006, or any other provisions that regulate, amend, replace or add such regulations. In addition, pursuant to our bylaws and in accordance the procedures described therein, our majority shareholder must include, in its list of candidates for the last two seats in the Board of Directors, the name of one individual jointly proposed by departments that produce hydrocarbons and one individual jointly proposed by the ten minority shareholders with the highest equity participation. According to Colombian law, the members of the Board of Directors must be elected at the annual shareholders’ meeting in accordance with a proportional representation system similar to cumulative voting (through an electoral quota voting system). The number of votes required to fill each position is calculated by dividing the number of possible votes by the number of open board positions. The members of the Board of Directors may be elected without an electoral quota voting system when there is unanimity. Pursuant to our bylaws, Directors are elected for a one-year term, and the positions are filled either by person or by position. Members of the Board may be reelected indefinitely. Currently, we have two members appointed by their position: the Minister of Finance and Public Credit and the Director of the National Planning Agency. Our current Directors were elected at the ordinary shareholders’ meeting held on March 31, 2015. Directors may be removed without cause at any moment by a majority of the shareholders present at a general shareholders’ meeting.

 

Our CEO is appointed by the Board of Directors and has two alternates. The CEO is elected for a two-year term, may be reelected indefinitely and freely removed prior to the expiration of his term. In accordance with our bylaws, the Board of Directors must evaluate the annual performance of the CEO and such results must be published in Ecopetrol’s web page or in an alternative media vehicle.

 

The compensation of our Directors is set exclusively by the shareholders at the general shareholders’ meeting. Directors are compensated for attending board meetings and committee meetings. A Board meeting requires a quorum of at least five members and decisions are approved with a majority of the Directors present. In the practice a consensus decision making operates in the Board.

 

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Under Colombian law, a director or executive officer must abstain from participating in any transaction that may result in a conflict of interest or that involves competition with the company, unless authorized at a general shareholders’ meeting. The general shareholders may approve or reject the transaction giving rise to the conflict of interest with the vote of the majority of the shares present at the shareholders’ meeting. If the director or executive officer who has the conflict is a shareholder, his or her vote must be excluded. We disclose conflicts of interest of our employees, executive officers and Directors in our annual reports.

 

Neither our bylaws nor our corporate governance code provide a retirement age for our Directors. Under our bylaws, there is no requirement for a person to have a minimum number of shares to be elected as a Director. Colombian law provides that Directors willing to sell or purchase shares in our Company need prior authorization from the entire Board of Directors. Colombian law does not impose any limitation as to the number of shares that may be acquired by a Director.

 

7.3.2Board Committees

 

Pursuant to our bylaws, our Board of Directors has four committees (audit and risk committee, corporate governance and sustainability committee, compensation and nomination committee and business committee), which establish guidelines, set specific actions and evaluate and submit proposals designed to improve performance in the areas under their supervision and control. These committees are comprised of members of the Board of Directors who are also appointed by the members of the Board of Directors and the chairman of each of the committees must be an independent Director. In addition to applicable regulations, the committees also have their own specific regulations that establish their purposes, duties and responsibilities.

 

Table 65 – Composition of committees of the Board of Directors as of April 22, 2016.

 

Audit and Risk Committee   Compensation and Nomination
Committee
  Corporate Governance and
Sustainability Committee
Horacio Ferreira Rueda
Jaime Ardila Gómez
Joaquín Moreno Uribe
Jorge Pinzón Sánchez
 

Minister of Finance and Public Credit
Carlos Cure Cure

Roberto Steiner Sampedro
Gustavo Carvajal Sinisterra
 

Horacio Ferrerira Rueda
Jorge Pinzón Sánchez
Roberto Steiner Sampedro
Carlos Cure Cure

         
Business Committee        
Minister of Finance and Public Credit
Horacio Ferreira Rueda
Joaquín Moreno Uribe
Carlos Cure Cure
Gustavo Carvajal Sinisterra
Jaime Ardila Gómez
Director of the National Planning Agency of Colombia
       

 

Audit and Risk Committee

 

Our audit and risk committee, which must be comprised of at least three members, all of them independent Directors, is our highest internal control body and provides support to our Board of Directors on risk, accounting and financial matters. It is in charge of guaranteeing the design, implementation and supervision of our internal control over financial reporting. It also ratifies the annual hydrocarbons reserves report and provides support for our Board on analyzing topics related to financial matters, risks, control environment and the assessment of the Company’s internal and external auditors.

 

All committee members are required to be knowledgeable in accounting matters and at least one of them is required to be an expert in financial and accounting matters.

 

Our Board of Directors has determined that Jaime Ardila Gómez qualifies as an “audit committee financial expert,” and he is independent under the definition of “independent” applicable to us under the rules of the NYSE.

 

The audit and risk committee approves on a case-by-case basis any engagement of our external independent auditors to provide services different than those related to auditing our financial statements. Occasionally, the audit and risk committee will have no doubt that these additional services do not compromise the external auditor’s independence. When in doubt, the committee will request the opinion of the internal auditor.

 

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Compensation and Nomination Committee

 

Our compensation and nomination committee, which must be comprised of at least three members, including at least one independent director, provides general guidelines for the selection and compensation of our executive officers and employees.

 

Corporate Governance and Sustainability Committee

 

Our corporate governance and sustainability committee, which must be comprised of at least three members, including at least one independent director, makes proposals to our Board of Directors to ensure and supervise the fulfillment of our good corporate governance and sustainability practices in accordance with our corporate governance code.

 

Business Committee

 

Our business committee, which must be comprised of at least five members, including at least one independent Director, assists our Board in analyzing potential business ventures. Based on its delegation of power, the committee studies and analyzes capital expenditure policies, major investment projects, strategy, new business and other matters that would help us move forward in our efforts toward the consolidation of our strategy. The primary criteria used in the committee’s decision-making process are the optimization of our portfolio and the proper allocation of our resources.

 

7.4Compliance with NYSE Listing Rules

 

The following is a summary of the significant differences between our corporate governance practices and those required for U.S. companies under the NYSE listing standards.

 

NYSE Standards   Our Corporate Governance Practices
     
Director Independence
 
The majority of the board of directors must be independent. §303A.01. “Controlled companies,” which would include Ecopetrol if we were a U.S. issuer, are exempt from this requirement. A controlled company is one in which more than 50% of the voting power is held by an individual, group or another company, rather than the public. §303A.00.   Pursuant to our bylaws, the majority of the Board of Directors must be independent. As of the date of this annual report, we have seven (7) independent Directors and two (2) non-independent Directors.
     
Executive Sessions
 
The non-management directors of each listed company must meet at regularly scheduled executive sessions without management. §303A.03.   A comparable rule does not exist under Colombian law. Except for our audit and risk committee, our Board of Directors does not meet without management.
     
Nominating/Corporate Governance and Sustainability Committee
 
A nominating/corporate governance and sustainability committee composed entirely of independent directors is required. The committee must have a charter specifying the purpose, duties and evaluation procedures of the committee. §303A.04. “Controlled companies” are exempt from these requirements. §303A.00.   Colombian law does not require the establishment of a nominating and a corporate governance and sustainability committee composed entirely of independent directors. Pursuant to our bylaws and board charter, these committees shall be composed of a majority of independent Directors.

 

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NYSE Standards   Our Corporate Governance Practices
     
Compensation Committee
 
A compensation committee composed entirely of independent directors is required, which must evaluate and approve executive officer compensation. The committee must have a charter specifying the purpose, duties and evaluation procedures of the committee. §303A.05. “Controlled companies” are exempt from this requirement. §303A.00.   Colombian law does not require the establishment of a compensation committee composed entirely of independent directors. Pursuant to our bylaws and board charter, this committee shall be composed of a majority of independent Directors.
     
Audit and Risk Committee
 
An audit committee with a minimum of three independent directors satisfying the independence and other requirements of Rule 10A-3 under the Exchange Act and the more stringent requirements under the NYSE standards is required. §§303A.06 and 303A.07.   According to Law 964 of 2005, Colombian companies that are authorized to issue securities by the Superintendency of Finance must have an audit committee that satisfies the requirements of Law 964 of 2005, including its minimum number of members, independence criteria and audit related duties. Our audit and risk committee is composed entirely of independent Directors, and the committee meets the requirements of Law 964 of 2005 and Rule 10A-3 under the Exchange Act.
     
Equity Compensation Plans
 
Equity compensation plans and all material revisions thereto require shareholder approval, subject to limited exemptions. §§303A.08 and 312.03.   Under Colombian law, no similar right to vote on equity compensation plans and material revisions thereto is given to shareholders. We do not give our shareholders the right to vote on equity compensation plans and material revisions thereto.
     
Corporate Governance Guidelines
 
Listed companies must adopt and disclose corporate governance guidelines. §303A.09.   The Superintendency of Finance recommends the adoption of corporate governance guidelines to all Colombian issuers. According to Superintendency of Finance Circular No. 028, 2014, the adoption of corporate governance guidelines is voluntary. Listed companies must annually publish a corporate governance survey comparing their corporate governance standards with those recommended by the Superintendency of Finance. Our corporate governance code and our survey of the adoption of Colombian practices are available on our website at http://www.ecopetrol.com.co.
     
Code of Ethics for Directors, Officers and Employees
 
Corporate governance guidelines and a code of business conduct and ethics is required, with disclosure of any waiver for directors or executive officers. The code must contain compliance standards and procedures that will facilitate the effective operation of the code. §303A.10.   We have adopted a code of ethics which complies with applicable U.S. and Colombian law. Our code of ethics applies to our chief executive officer, chief financial officer, principal accounting officer, persons performing similar functions and generally to all the employees, members of the Board of Directors, suppliers, and contractors of Ecopetrol S.A. and its corporate group. Our code of ethics is available on our website at http://www.ecopetrol.com.co.

 

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7.5Management

 

The following presents information concerning our executive officers and senior management. Unless otherwise noted, the majority of these individuals are Colombian citizens.

 

Juan Carlos Echeverry (53) has served as the Chief Executive Officer of Ecopetrol, Colombia’s National Oil Company, since April 2015. He has previously served as Colombia’s Minister of Finance and Minister of Economic Planning. During his mandate as Minister of Finance in 2011, four international publications (The Banker, America Economía, Emerging Markets, and Institutional Investor) awarded him as the Best Finance Minister of the Americas. Previously, Mr. Echeverry represented Colombia in the Board of Directors of the Inter-American Development Bank (Washington D.C.) and served as Dean of Economics at Universidad de los Andes (Bogotá), and Associate Professor of Economics at Instituto de Empresa in Madrid, Spain and in Universidad de los Andes. In 2002 he founded Econcept SAS, a consulting firm on economics dedicated to advising foreign and domestic firms investing in Colombia, serving as expert witnesses in arbitration and micro and macro-economic consulting. He is the author of several books about the Colombian economy and co-author of publications focusing on developing economies. Among his work there are economic studies on Africa and countries of the Pacific Basin. Mr. Echeverry has a Ph.D. in Economics from New York University and an outstanding academic career in the field of Economics.

 

Felipe Bayon Pardo (50) has served as the Executive Vice President of Ecopetrol since February 2016. Mr. Bayon holds a degree in Mechanical Engineering from the Universidad de los Andes. He has over 24 years of experience in the oil and gas industry. For the last 20 years, he worked at BP plc, most recently as Senior Vice President of BP America and Head of Global Deepwater Response. From 2005 to 2010, he was the Regional President of BP Southern Cone (South America), and prior to 2005 he worked in BP’s headquarters as Chief of Staff to the CEO and the Head of the Executive Office for Exploration and Production. He began his career in 1995 in BP Colombia, as a Project Engineer, where he held various positions until becoming Vice President of Operations in Colombia.

 

María Fernanda Suárez (41) has served as the Chief Financial Officer of Ecopetrol since August 2015. Ms. Suárez holds a degree in Business Administration from CESA and a master’s degree in Policy Management from Georgetown University. Ms. Suárez has 19 years of experience in the public and private sectors. She has held various positions in these sectors, including Public Credit Manager at Ministry of Finance and Public Credit in the Treasury Department, Investment Chief Officer at Porvenir and other high-level positions at Citibank, ABN AMRO and Bank of America. She has served on the board of directors for ISA, Isagen, XM, FEN and Banco Agrario.

 

Hector Manosalva (52) joined Ecopetrol in 1986 and has served as Vice-President for Development and Production since July 2010. Mr. Manosalva holds a degree in Petroleum Engineering from the Universidad de América in Bogotá, and completed post-graduate studies in finance at the Universidad EAFIT and Executive Management at the Universidad de los Andes. Over the course of his career at Ecopetrol, Mr. Manosalva has held various positions, including Executive Vice-President for Production and Exploration, Vice-President of Production, Production Manager of the Central Region, President of Colombia’s Advisor for Safety and Security of National Energy Infrastructure, Director of HSE and Corporate Social Responsibility, Production Manager of the Southern Region and Head of the Production Planning Division.

 

Max Torres (58) has served as Exploration Vice President since September 2014. Mr. Torres holds a B.S. degree in Geology from Universidad Nacional of Tucumán in Argentina and an M.S. in Stratigraphy from Georgia State University. He has more than 28 years of experience in oil and gas exploration and production and is a proven world class oil and gas finder and a champion of Latin American oil and gas exploration. Among his many professional accomplishments, Mr. Torres was directly responsible for the 16 Tcfg Perla gas field discovery in Venezuela, the 275 Tcfg super giant Galkynysh gas field discovery in Turkmenistan, as well as other oil and gas discoveries. Prior to joining Ecopetrol, Mr. Torres worked at Repsol from 1997 to 2013 as Exploration Director for Europe and the Middle East, Exploration Director for Europe and Africa and Exploration Director for Latin America.

 

Jaime Bocanegra (47) has served as Vice President of Transportation since April 2013. Mr. Bocanegra holds a bachelor’s degree in Petroleum Engineering from Universidad de América in Colombia, a specialization degree in Management, a specialization degree in Management of Oil and Gas Industry Assets and Strategic Leadership. He has worked for Ecopetrol for the last 23 years and has held various positions within the company, including Interim Vice President of Sustainable Development and Environmental, Plant Coordinator, Multipurpose Pipelines Manager, Chief of Operations and Maintenance Department, Dosquebradas Program Manager and Centralized Operations Manager.

 

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Thomas Rueda Ehrhardt (42) has served as Cenit’s Chief Executive Officer since November 2014. Mr. Rueda holds a degree in Business Administration from Los Andes University (Bogotá) with continuing studies in Management at Cambridge University (England) and Organizational Development at Duke University (Calgary). He has more than 19 years of experience in the oil and gas sector. He began his career at BP where he held various positions, including the Pipeline and Crude Oil Export Manager, Planning Manager, Financial Manager for BP Angola Business Unit, and Planning Manager for E & P at BP Headquarters. He also worked for Talisman as their Asset Manager for Piedemonte and Ocensa. He joined Cenit in 2013 as Chief Financial Officer.

 

Tomas Hernandez (61) has served as Vice President of Refining and Industrial Processes since February 2016. He has over 37 years of international experience in the oil and gas sector. He has served as Business Manager at Chevron’s Pascagoula refinery in the United States, General Manager for Marketing Operations for Chevron Texaco in Latin America and Africa-Europe-Pakistan Regions and has spent over 20 years in managerial positions in various refineries at Chevron. Prior to joining Ecopetrol, he was Deputy Upgrader Manager at Petropiar, a joint venture in which Chevron participates. Mr. Hernandez holds a degree in Chemical Engineering from the University of Missouri – Rolla (University of Science and Technology Missouri).

 

Juan Pablo Ospina (48) has served as the Vice President of Sales and Marketing since May 2015. Mr. Ospina holds a bachelor degree in Mechanical Engineering from Universidad Pontificia Bolivariana de Medellín, and completed studies in management and leadership at University of North Carolina and the Thunderbird Management School in Phoenix, Arizona. During his 20 years of experience in the oil and gas industry, he has built a career in sales, marketing and economic regulation. He has worked for Grupo Empresarial Ecopetrol for more than seven years; five directly with Ecopetrol S.A. in different roles as the leading expert in new business development and as the refined products sales manager. Before joining Ecopetrol, he was Commercial Director for Cenit, Ecopetrol’s subsidiary for transport and logistics of oil and refined products within the country.

 

Carlos Alberto Vargas Medina (46) has served as Vice President of Transformation since December 2015. Mr. Vargas holds a degree in Petroleum Engineering from America University. He has 23 years of experience across the integrated oil and gas value chain with a focus in drilling and well interventions and an expertise in exploration, appraisal, development and production onshore and offshore wells. He has held management positions in the United Kingdom, Argentina, Bolivia and Colombia, where he has developed key skills in strategy, performance management systems, risks management, HSE and integration of multicultural and multidisciplinary teams. Prior to taking his current position, he was the Vice President of Drilling and Completions at Equion.

 

Fernán Ignacio Bejarano Arias (60) has served as Vice-president of Legal Affairs and General Counsel at Ecopetrol since March 2016. Mr. Bejarano Arias holds a bachelor’s degree in Law from Universidad Javeriana in Bogotá and an LLM from the American University (Washington D.C.). In his more than thirty years of professional experience, he has been a partner at the law firms of Estudios Palacios Lleras S.A, Bejarano Cárdenas y Ospina y Asociados Ltda and OPEBSA Compañía de  Abogados S.A.S. and has worked for several years at important positions in the public sector, such as the Vice Minister of Foreign Affairs, Secretary of the Monetary Board, Secretary of the Board of Directors of the Banco de la República (Colombian Central Bank),  Office of Legal Affairs Counselor at the Presidency of the Republic of Colombia, Vice-president of Legal Affairs and General Counsel at Corporación Finaciera Colombiana. Mr. Bejarano Arias has been a professor at the Faculty of Law of the Universidad Javeriana, and has been arbitrator before the Center for Arbitration and Conciliation of the Bogotá Chamber of Commerce.

 

María Juliana Alban (41) has served as Compliance Vice-president and Compliance Officer since July 2015. Ms. Alban holds a law degree from Universidad Sergio Arboleda with a specialization in Commercial and Financial Law from the same institution. Since 2007, Ms. Alban has worked in the Attorney General’s Office (Procuraduría General de la Nación) as Secretary General and Chief of Legal Office, among other positions within the institution.

 

Alejandro Arango (56) has served as Vice president of Human Resources at Ecopetrol S.A. since October 2014. He has more than 20 years of professional experience around the world and has worked as a Vice President of Human Resources at Banco Santander in Colombia and as Human Resources Director of the Consumer Finance Division, Strategy Division and Cards Division at Banco Santander in Spain. Mr. Arango has also served as Human Resources Director for the Asia Pacific region at Banco Santander in Hong Kong and as a Global Human Resources Division T&O, among others. Mr. Arango holds a degree in Strategic Marketing from CESA School of Business and a bachelor’s degree in Theology from the Universidad Hochschule Sankt Georgen (Frankfurt) and a bachelor’s degree in Philosophy from Javeriana University.

 

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Andrés Mantilla (45) has served as the Director of the Colombian Petroleum Institute of Ecopetrol, the technology development center of the company, since September 2013, and has served as Deputy Vice President of Innovation and Technology since November 2015. He holds a degree in Petroleum Engineering from Universidad Industrial de Santander, Colombia, a master’s of science in Petroleum Engineering from Stanford University, and a Ph.D. in Geophysics from Stanford University. His professional work includes participation, leadership and management of technical teams and technology development, demonstration and implementation projects in the oil and gas industry. He worked for Ecopetrol holding various positions between 1994 and 2006. Before rejoining Ecopetrol in 2013, he worked for BP Colombia, Marathon Oil Company and Maersk Oil. During his professional career he has had exposure to exploration and production projects and the evaluation of new ventures in Colombia, the Gulf of Mexico, the North Sea, West Africa, South America and the Middle East.

 

Eduardo Uribe Botero (56) has served as Vice President of Sustainable Development and Environmental since August 2015. Mr. Uribe holds a degree in Agricultural Engineering from Caldas University, a master’s of science in Soil Chemistry and a Ph.D. in Fertility and Management of Tropical Soils. He has over 25 years of experience in the private and public sectors. In 1994, he was appointed the first Vice Minister of the Environment in Colombia. In recent years he has served as a strategic, environmental and social advisor to companies and organizations in the fields of hydrocarbons, mining, energy, forestry, environmental and agribusiness through the consulting firm Optim Consulting.

 

María Consuelo Rodríguez (43) has served as Director of Corporate Affairs since September 2015. Mrs. Rodriguez holds a degree in law from Universidad Externado de Colombia with a specialization in Economic Law and Telecommunication Regulation and Management from the same institution. She served as Secretary of Cabinet of the Ministry of Defense until July 2015. During her legal career she has worked with and advised entities such as the President of the Republic, the Ministry of Finance and Public Credit, the National Planning Agency and the Superintendency of Health and Finance, among others. Mrs. Rodriguez has experience in constitutional, administrative and tax matters in various public and private entities, as well as management of non-profit organizations, crisis care, strategic communications and high-level dialogue with the state, private and nongovernmental sectors.

 

Carlos Eduardo Zamudio Rojas (50) has served as the Director of the Shared Services Center of Ecopetrol in Colombia since August 2012. Mr. Zamudio has more than 20 years of professional experience and holds degrees in Management and Finances from the Universidad Javeriana and Universidad de los Andes, respectively. He has extensive experience in service delivery operations in multinational companies at regional and global levels, including Belcorp and Procter & Gamble. At Belcorp, a leader in the beauty industry in Latin America, he was Corporate Director of the Shared Services Center where he covered 15 countries including the United States and Brazil. While at Procter & Gamble he was a recognized as a leader in the Latin America region, as the Corporate Manager of Finance in Chile, Brazil, Costa Rica and Colombia, as well as the Global Business Services Manager for Latin America.

 

Margarita Escobar Pereira (34) has served as Secretary General and Secretary of the Board of Directors since August 2015. Mrs. Escobar holds a law degree from Colegio Mayor de Nuestra Señora del Rosario with a specialization in Tax Law from the same institution. Prior to joining Ecopetrol, Mrs. Escobar worked as pre-graduate and post-graduate professor in financial law at Universidad del Rosario and as Chief Legal Adviser of the Ministry of Finance and Public Credit. She has also served as Deputy Superintendent of the Health Superintendence of the Nation, an advisor in National Department of Planning and an advisor in the General Department of the Presidency of the Republic of Colombia.

 

None of our Directors or executive officers has any familial relationship with any Director or executive officer.

 

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7.6Compensation of Directors and Management

 

Based on a resolution adopted at our annual shareholders’ meeting in 2012, compensation for Directors’ attendance in person at meetings of the Board of Directors and/or committee meetings increased from the equivalent of four to six minimum monthly wage salaries, which totals approximately COP$3.9 million for 2015 and COP$3.7 million for 2014. Fees for attendance at virtual meetings are set at 50% of the in-person meeting fee.

 

The total compensation paid to our Directors, executive officers and senior management during 2015 amounted to COP$16.4 billion.

 

Our Directors are not eligible to receive pension and retirement benefits from us. The total amount set aside to provide pension and retirement benefits to our eligible executive officers totals COP$10.3 billion.

 

7.7Share Ownership of Directors and Executive Officers

 

No individual Director or executive officer beneficially owns more than 1% of our outstanding shares.

 

Table 66 – The following Directors and executive officers own shares of Ecopetrol:

 

Director  Shares   % 
Joaquín Moreno Uribe   127,988    0.0003113%
Mauricio Cárdenas Santamaría   2,000    0.0000049%
Roberto Steiner Sampedro   50,000    0.0001216%
Juan Carlos Echeverry Garzón   33,420    0.0000813%

 

Executive Officer  Shares   % 
Héctor Manosalva   49,380    0.0001201%

 

Under Colombian law, all of our shareholders have the same economic privileges and voting rights.

 

7.8Controls and Procedures

 

Disclosure Controls and Procedures

 

As required by Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as of December 31, 2015, we evaluated the design and effectiveness of our financial disclosure controls and procedures under the supervision and participation of our management, including our Chief Executive Officer and Chief Financial Officer. There are inherent limitations to the effectiveness of any system of disclosure controls and procedures, including the possibility of human error and the circumvention or overriding of the controls and procedures. Accordingly, even if effective, disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives.

 

Based upon this evaluation, our Chief Executive Officer and Chief Financial Officer concluded that as of the end of the period covered by this annual report, our disclosure controls and procedures were effective to provide reasonable assurance that the information required to be disclosed in the reports that we file and submit under the Securities Exchange Act of 1934 is recorded, summarized and reported as and when required and is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.

 

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Management’s Annual Report on Internal Control over Financial Reporting

 

Our management is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15(d)-15(f) under the Securities Exchange Act of 1934. Our internal control over financial reporting is a process designed under the supervision of our Chief Executive Officer and Chief Financial Officer, and affected by our board of directors, management and other personnel, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of our financial statements for external reporting purposes in accordance with generally accepted accounting principles, and it includes those policies and procedures that:

 

·pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect transactions and dispositions of our assets;

 

·provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures are being made only in accordance with authorization of our management and directors; and

 

·provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on our financial statements.

 

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Therefore, effective control over financial reporting cannot, and does not, provide absolute assurance of achieving our control objectives. Also, projection of any evaluation of the effectiveness of the internal controls to future periods is subject to the risk that controls may become inadequate because of changes in conditions or that the degree of compliance with the policies or procedures may deteriorate.

 

As of the year ended December 31, 2015, our management conducted an assessment of the effectiveness of our internal control over financial reporting in accordance with the criteria established in the publication “Internal Control – Integrated Framework (2013)”, issued by the Committee of the Sponsoring Organizations of the Treadway Commission, as well as the rules set by the SEC in its Final Rule “Management’s Report on Internal Control Over Financial Reporting and Certification of Disclosure in Exchange Act Periodic Reports.”

 

Based on the assessment performed, management concluded that our internal control over financial reporting was effective as of the end of the period covered by this annual report.

 

The effectiveness of our internal control over financial reporting has been audited by PricewaterhouseCoopers Ltda., an independent registered public accounting firm, as stated in their audit report accompanying our consolidated financial statements.

 

Audit and Non-Audit Fees

 

Our consolidated financial statements for the fiscal years ended December 31, 2015 and December 31, 2014 were audited by PricewaterhouseCoopers Ltda.

 

The following table sets forth the fees billed to us by PricewaterhouseCoopers Ltda. during the fiscal year ended December 31, 2015 and 2014.

 

Table 67 – Fees Billed to us by PricewaterhouseCoopers Ltda.

 

   As of December 31, 
   2015   2014 
   (in millions of Colombian Pesos,
excluding 16% value added tax)
 
Audit fees   8,199    9,533 
Audit-related fees   606    458 
Tax fees   -    30 
All other fees (1)   5    65 
Total   8,810    10,086 

 

 

(1)These fees are comprised of coaching sessions in management skills dictated to officers of some affiliates as well as participation in open training courses.

 

Audit Fees. The audit fees listed in the table above are the aggregated fees billed by PricewaterhouseCoopers Ltda. in connection with their audits of our annual consolidated financial statements (IFRS), interim consolidated financial statements (under IFRS), subsidiary audits (under local GAAP) and review of periodic documents filed with the SEC. In addition, these audit fees include fees related to our independent auditors’ audits of our internal controls over financial reporting.

 

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Audit-related Fees. The audit-related fees listed in the table above are the fees billed by PricewaterhouseCoopers Ltda. in connection with their agreed-upon procedures of our variable compensation bonus system as well as the audit of the joint operation agreement of Ecopetrol Germany GmbH.

 

Tax Fees. The tax fees listed in the table above correspond to (1) assisting some subsidiaries in the preparation and filing of appropriate tax returns with the tax authorities (including electronic filings), (2) advising some subsidiaries about the tax consequences associated with new or proposed legislation and (3) rendering advice to some subsidiaries on the likely tax consequences of proposed transactions and the appropriate methods of structuring and reporting.

 

Changes in Internal Control over Financial Reporting

 

There were no changes made in our internal control over financial reporting during the year ended December 31, 2015 that have materially affected or are reasonably likely to materially affect the Company’s internal controls over financial reporting.

 

Change in Registrant’s Certifying Accountant

 

At the ordinary general shareholders’ meeting on March 31, 2016, the shareholders of Ecopetrol S.A. dismissed PricewaterhouseCoopers Ltda. and appointed Ernst & Young Ltda. as recommended by the Company’s Audit Committee, as the new independent registered public accounting firm.

 

During the Company’s two fiscal years ended December 31, 2015 and 2014 and subsequent interim periods through the date of its report, there were no disagreements with PricewaterhouseCoopers Ltda. on any matter of accounting principles or practices, financial statement disclosure, or auditing scope or procedure, which disagreements if not resolved to the satisfaction of PricewaterhouseCoopers Ltda. would have caused them to make reference thereto in their reports on the consolidated financial statements for such periods.

 

During the Company’s two most recent fiscal years ended December 31, 2015 and 2014 and the subsequent periods through the date of its report, there have been no reportable events (as defined in Item 16F(a)(1)(v) of Form 20-F).

 

We have not previously consulted with Ernst & Young Ltda. regarding either (i) the application of accounting principles to a specific completed or contemplated transaction; (ii) the type of audit opinion that might be rendered on our financial statements; or (iii) a reportable event (as provided in 16F(a)(1)(v) of Form 20-F) during the years ended December 31, 2015 and 2014, or any later interim period, including the interim period up to and including the date of its report.

 

We have provided PricewaterhouseCoopers Ltda. with a copy of the foregoing disclosure, and have requested that PricewaterhouseCoopers Ltda. furnish us with a letter addressed to the SEC stating whether or not PricewaterhouseCoopers Ltda. agrees with such disclosure, which we attach to this report as Exhibit 16.1 as required by Item 16F(a)(3) of Form 20-F.

 

Attestation Report of the Registered Public Accounting Firm

 

PricewaterhouseCoopers Ltda.’s attestation report on our internal control over financial reporting is included in their audit report accompanying our consolidated financial statements. See Report of Independent Registered Public Accounting Firm—PricewaterhouseCoopers Ltda. to the consolidated financial statements.

 

Significant Changes

 

For a description of significant events since December 31, 2015, please see Note 36 – Subsequent events to our consolidated financial statements.

 

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8.Financial Statements

 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

 

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Contents

 

Report of Independent Registered Public Accounting Firm F-2
   
Consolidated statement of financial position F-3
   
Consolidated statement of profit or loss F-4
   
Consolidated statement of other comprehensive income F-5
   
Consolidated statement of changes in equity F-6
   
Consolidated statement of cash flows F-7
     
1. Reporting entity F-8
     
2. Basis of presentation F-8
     
3. Significant accounting judgments and estimations F-10
     
4. Accounting policies F-12
     
5. New standards issued by the IASB F-23
     
6. Cash and cash equivalents F-24
     
7. Trade and other receivables F-24
     
8. Inventories F-25
     
9. Taxes F-26
     
10. Equity instruments measured at fair value F-30
     
11. Other financial assets F-31
     
12. Other assets F-33
     
13. Non-current assets held for sale and associated liabilities F-33
     
14. Investments in associates and joint ventures F-34
     
15. Property, plant and equipment F-37
     
16. Natural and environmental resources F-38
     
17. Intangibles F-39
     
18. Impairment of Property, plant and equipment, Natural resources and Intangibles F-40
     
19. Goodwill F-42
     
20. Loans and borrowings F-43
     
21. Trade and other payables F-46
     
22. Provision for employees benefits F-46
     
23. Accrued liabilities and provisions F-49
     
24. Derivative financial instruments F-52
     
25. Equity F-53
     
26. Sales revenue F-55
     
27. Cost of sales F-56
     
28. Administration, operation and project expenses F-56
     
29. Impairment of non-current assets and other operating income and (expenses) F-57
     
30. Finance result, net F-57
     
31. Risk management F-58
     
32. Related parties F-62
     
33. Joint Operations F-64
     
34. Segment information F-66
     
35. First-time adoption of International Financial Reporting Standards - IFRS F-70
     
36. Subsequent events F-75
     
Supplemental information on Oil and Gas producing activities (unaudited by PwC) F-76
   
Exhibit 1 - Consolidated companies, associates and joint ventures F-79

 

 F-1 

 

 

Report of Independent Registered Public Accounting Firm

 

To the Board of Directors and Shareholders of

Ecopetrol S. A.

 

In our opinion, the accompanying consolidated statement of financial position and the related consolidated statement of profit or loss, statement of other comprehensive income, statement of changes in equity and statement of cash flows present fairly, in all material respects, the financial position of Ecopetrol S. A. and its subsidiaries (the “Company”) at December 31, 2015, December 31, 2014, and January 1, 2014 and the results of their operations and their cash flows for each of the two years in the period ended December 31, 2015 in conformity with International Financial Reporting Standards as issued by the International Accounting Standards Board. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2015, based on criteria established in Internal Control - Integrated Framework 2013 issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The Company's management is responsible for these financial statements, for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in Management’s Annual Report on Internal Control over Financial Reporting appearing under Item 7.8 (Controls and Procedures). Our responsibility is to express opinions on these financial statements and on the Company's internal control over financial reporting based on our integrated audits. We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

 

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

 

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

 

/s/ PricewaterhouseCoopers Ltda.

 

Bogotá, Colombia

April 28, 2016

 

 F-2 

 

 

Ecopetrol S.A.

Consolidated statement of financial position

At December 31, 2015, December 31, 2014 and January 1, 2014

(Figures expressed in millions of Colombian pesos)

 

      December 31,   December 31,   January 1, 
   Notes  2015   2014   2014 
Assets                  
Current assets                  
Cash and cash equivalents  6   6,550,450    7,618,178    8,805,090 
Trade and other receivables  7   3,427,412    4,287,553    5,804,495 
Inventories  8   3,057,958    2,929,921    3,559,586 
Tax assets  9   4,501,734    2,019,066    1,545,535 
Equity instruments measured at fair value  10   913,488    1,581,466    1,505,033 
Other financial assets  11   329,227    817,977    1,547,133 
Other current assets  12   1,090,324    1,385,116    930,883 
       19,870,593    20,639,277    23,697,755 
Non-current assets held for sale  13   242,745    1,362    1,362 
       20,113,338    20,640,639    23,699,117 
Non-current assets                  
Investments in associates and joint ventures  14   1,931,934    2,390,189    2,657,198 
Trade and other receivables  7   584,571    435,404    356,373 
Property, plant and equipment  15   65,105,073    55,665,007    46,599,417 
Natural and environmental resources  16   24,043,297    24,120,664    21,725,479 
Intangibles  17   388,051    245,152    272,070 
Deferred tax assets  9   8,239,472    4,245,416    3,893,883 
Other financial assets  11   1,256,152    663,842    504,500 
Goodwill  19   1,159,922    1,426,822    1,426,822 
Other non-current assets  12   766,380    1,090,716    941,056 
       103,474,852    90,283,212    78,376,798 
Total Assets      123,588,190    110,923,851    102,075,915 
                   
Liabilities                  
Current liabilities                  
Loans and borrowings  20   4,573,620    3,517,522    3,121,068 
Trade and other payables  21   7,757,277    8,798,965    9,966,622 
Labor and pension plan obligations  22   1,392,266    1,379,706    1,337,616 
Tax liabilities  9   2,803,559    1,896,938    2,966,470 
Accrued liabilities and provisions  23   653,497    842,957    1,047,597 
Other financial liabilities  24   101,319    140,055    46 
Other liabilities      144,441    267,587    249,286 
       17,425,979    16,843,730    18,688,705 
Liabilities related to assets held for sale  13   17,628    -    - 
       17,443,607    16,843,730    18,688,705 
                   
Non-current liabilities                  
Loans and borrowings  20   48,649,718    31,524,106    19,572,195 
Trade and other payables  21   6    30,439    37,383 
Labor and pension plan obligations  22   2,459,849    4,419,987    5,414,008 
Deferred tax liabilities  9   6,026,050    4,168,144    4,119,815 
Accrued liabilities and provisions  23   5,423,850    4,995,114    3,870,749 
Other non-current liabilities      484,147    408,103    508,491 
       63,043,620    45,545,893    33,522,641 
Total liabilities      80,487,227    62,389,623    52,211,346 
                   
Equity  25               
Equity attributable to owners of the Company      41,225,908    47,022,946    48,598,996 
Non-controlling interests      1,875,055    1,511,282    1,265,573 
Total Equity      43,100,963    48,534,228    49,864,569 
Total liabilities and equity      123,588,190    110,923,851    102,075,915 

 

 F-3 

 

 

Ecopetrol S.A.

Consolidated statement of profit or loss

(Figures expressed in millions of Colombian pesos, except for the earnings (loss) per share, expressed in Colombian pesos)

 

      For the years ended December 31, 
   Notes  2015   2014 
            
Revenue  26   52,347,271    65,971,888 
Cost of sales (before impairment of non-current assets)  27   36,994,516    42,975,128 
Gross profit (excluding impairment)      15,352,755    22,996,760 
              
Administration expenses  28   1,700,985    1,031,035 
Operation and project expenses  28   4,034,268    5,520,325 
Impairment of non-current assets  29   7,864,875    2,304,567 
Other operating income and expenses, net  29   (378,538)   (308,194)
Operating income      2,131,165    14,449,027 
              
Finance results, net  30          
Financial income      621,924    399,818 
Financial expenses      (2,718,414)   (1,640,294)
Foreign exchange loss, net      (5,566,614)   (2,270,193)
       (7,663,104)   (3,510,669)
              
Share of profit of associates and joint ventures  14   (46,687)   166,070 
(Loss) Income before income tax      (5,578,626)   11,104,428 
Income tax  9   (710,353)   (5,434,855)
Net (loss) income for the period      (6,288,979)   5,669,573 
              
Net (loss) income attributable to:             
Owners of the Company      (7,193,859)   5,046,517 
Non-controlling interest      904,880    623,056 
       (6,288,979)   5,669,573 
(Loss) Earnings per share (basic and diluted)      (175.0)   122.7 

 

 F-4 

 

 

ECOPETROL S. A.

Consolidated statement of other comprehensive income

(Figures expressed in millions of Colombian Pesos)

 

      For the years ended December 31, 
   Note  2015   2014 
            
Net (loss) income for the period      (6,288,979)   5,669,573 
              
Components of comprehensive income of income tax that may be reclassified subsequently to profit or loss (net of tax):             
              
Accumulated foreign currency translation  2.4   5,979,644    3,398,374 
Net fair value gain (Loss) on equity instruments measured at fair value  10   (106,911)   76,435 
Realized gain on proceeds from sales of equity instruments measured at fair value  25.5   (19,405)   - 
Cash Flow Hedge for Future Company Exports  31   (217,291)   - 
Cash flow Hedges - Derivative financial instruments  24   (60,083)   - 
       5,575,954    3,474,809 
Components of comprehensive income of income tax that will not be reclassified subsequently to profit or loss (net of tax):             
              
Remeasurement of defined benefit obligation, net of taxes  22   1,404,602    743,793 
Others      58,643    - 
Other comprehensive income for the period      7,039,199    4,218,602 
Total comprehensive income      750,220    9,888,175 
              
Attributable to:             
Shareholders      (328,604)   9,114,221 
Non-controlling interests      1,078,824    773,954 
       750,220    9,888,175 

 

 F-5 

 

 

ECOPETROL S.A.

Consolidated statement of changes in equity

(Figures expressed in millions of Colombian Pesos)

 

   Note 

Subscribed

and paid-in

capital

  

Additional

paid-in

capital

  

Legal

reserves

  

Other

reserves

  

Other

comprehensive

income

  

Retained

earnings/deficit

  

Equity

attributable

to owners of

the

Company

  

Non-

controlling

interests

   Total Equity 
                                        
Balance as of December 31, 2014      10,279,175    6,607,612    5,271,104    13,170,694    3,980,749    7,713,612    47,022,946    1,511,282    48,534,228 
Net income (loss)      -    -    -    -    -    (7,193,859)   (7,193,859)   904,880    (6,288,979)
Dividends declared  25   -    -    -    -    -    (5,468,521)   (5,468,521)   (715,051)   (6,183,572)
Capitalization of reserves  25   14,760,895    -    -    (14,760,893)   -    -    2    -    2 
Diluted shares      (2)   -    -    -    -    -    (2)   -    (2)
Change of interest share in controlled entities      -    -    -    -    -    -    -    -    - 
Additions to paid-in capital      -    5    -    -    -    -    5    -    5 
Additional paid-in capital receivable      -    82    -    -    -    -    82    -    82 
Release of occasional reserves  25   -    -    -    (12,823,783)   -    12,823,783    -    -    - 
Appropriation of reserves  25   -    -    -    -    -    -         -      
Legal      -    -    (43,378)   -    -    43,378    -    -    - 
Fiscal      -    -    -    466,503    -    (466,503)   -    -    - 
Occasional      -    -    -    15,215,797    -    (15,215,797)   -    -    - 
Other comprehensive income      -    -    -    -    -    -         -      
Actuarial valuation  22   -    -    -    -    1,404,602    -    1,404,602    -    1,404,602 
Net fair value (loss) on equity instruments measured at fair value  10   -    -    -    -    (126,316)   -    (126,316)   -    (126,316)
Cash Flow Hedge for Future Company Exports  31   -    -    -    -    (217,291)   -    (217,291)   -    (217,291)
Cash flow Hedges - Derivative financial instruments  24   -    -    -    -    (43,590)   -    (43,590)   (16,493)   (60,083)
Others      -    -    -    -    58,643    -    58,643    -    58,643 
Foreign currency translation      -    -    -    -    5,789,207    -    5,789,207    190,437    5,979,644 
Balance as of December 31, 2015      25,040,068    6,607,699    5,227,726    1,268,318    10,846,004    (7,763,907)   41,225,908    1,875,055    43,100,963 
                                                 
Balance as of January 1, 2014      10,279,175    6,607,541    5,033,539    10,354,141    (86,955)   16,411,555    48,598,996    1,265,573    49,864,569 
Net income      -    -    -    -    -    5,046,517    5,046,517    623,056    5,669,573 
Dividends declared  25   -    -    -    -    -    (10,690,342)   (10,690,342)   (516,331)   (11,206,673)
Change of interest share in controlled entities      -    -    -    -    -    -    -    (11,914)   (11,914)
Additions to paid-in capital      -    42    -    -    -    -    42    -    42 
Additional paid-in capital receivable      -    29    -    -    -    -    29    -    29 
Release of occasional reserves  25   -    -    -    (10,161,138)   -    10,161,138    -    -    - 
Appropriation of reserves  25   -    -    -    -    -    -         -      
Legal      -    -    237,565    -    -    (237,565)   -    -    - 
Occasional      -    -    -    12,977,691    -    (12,977,691)   -    -    - 
Other comprehensive income      -    -    -    -    -    -         -      
Actuarial valuation  22   -    -    -    -    743,793    -    743,793    -    743,793 
Net fair value gain on equity instruments measured at fair value      -    -    -    -    76,435    -    76,435    -    76,435 
Foreign currency translation  10   -    -    -    -    3,247,476    -    3,247,476    150,898    3,398,374 
Balance as of December 31, 2014      10,279,175    6,607,612    5,271,104    13,170,694    3,980,749    7,713,612    47,022,946    1,511,282    48,534,228 

 

 F-6 

 

 

ECOPETROL S. A.

Consolidated statement of cash flows

(Figures expressed in millions of Colombian Pesos)

 

      2015   2014 
   Note        
Cash flow provided by operating activities:             
Net (loss) income  Equity holders of Ecopetrol      (7,193,859)   5,046,517 
Adjustments to reconcile net (loss)  income to cash provided by operating activities:             
Non-controlling interests      904,880    623,056 
Income tax  9   710,353    5,434,855 
Depreciation, depletion and amortization  15- 16 - 17   6,770,358    6,417,207 
Foreign exchange loss, net      5,566,614    2,270,193 
Finance costs recognized in profit or loss      2,396,445    1,405,331 
Gain on disposal of non-current assets      59,932    231,899 
Impairment of assets  29   7,856,177    2,381,413 
Fair value loss (gain) on financial assets valuation      (109,673)   135,427 
Share or profit of associates and joint ventures  14   46,687    (166,070)
Gain on sale of equity instruments measured at fair value  10   (72,339)   - 
Realized foreign exchange cash flow hedges  31   (7,646)   - 
Net changes in operating assets and liabilities             
Accounts and notes receivable      751,031    1,507,923 
Inventories  8   (183,231)   610,843 
Accounts payable  7   (2,202,808)   (322,819)
Taxes payable  9   (1,964,995)   (3,124,887)
Labor obligations  22   (206,444)   (259,043)
Estimated liabilities and provisions  23   (216,939)   (146,499)
Other assets      654,960    (653,196)
Income tax paid      (3,148,028)   (4,819,169)
Cash provided by operating activities      10,411,475    16,572,981 
              
Cash flows from investing activities:             
Investment in property, plant and equipment  15   (8,548,933)   (8,923,568)
Investment in natural and environmental resources  16   (5,590,321)   (5,038,296)
Acquisition of intangibles  17   (112,255)   (112,018)
Proceeds from sales of equity instruments measured at fair value  10   613,998    - 
Sales of other financial assets      1,208,898    1,313,837 
Interest received      293,507    286,527 
Dividends received      423,856    720,217 
Proceeds from sales of property, plant and equipment      166,211    184,424 
Net cash used in investing activities      (11,545,039)   (11,568,877)
              
Cash flows from financing activities:             
Proceeds from borrowings  20   10,985,933    9,094,818 
Repayments of borrowings  20   (4,903,592)   (2,693,104)
Interest paid      (1,981,127)   (1,231,392)
Capitalizations  25   3    41 
Dividends paid  25   (5,493,400)   (12,516,566)
Net cash used in financing activities      (1,392,183)   (7,346,203)
              
Exchange difference in cash and cash equivalents      1,458,019    1,155,187 
Net increase in cash and cash equivalents      (1,067,728)   (1,186,912)
Cash and cash equivalents at the beginning of the year      7,618,178    8,805,090 
Cash and cash equivalents at the end of the year      6,550,450    7,618,178 
Non-cash transactions             
Payment of income tax through offset of recoverable balances      894,451    - 
Capitalization of reserves      14,760,895    - 
Remittances financed for the payment of imports      662,099    457,367 

 

F-7 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

1.Reporting entity

 

Ecopetrol S.A. is a mixed economy company, with a commercial nature, constituted in 1948 in Bogotá - Colombia. Its corporate purpose is to develop commercial or industrial activities arising from or related to the exploration, production, refining, transportation, storage, distribution, and selling of hydrocarbons, their by-products and associated products on its own or through its subsidiaries (“Ecopetrol”, the “Company” or Ecopetrol Business Group).

 

11.51% of Ecopetrol S.A.’s shares are publicly traded on the Stock Exchanges of Colombia; New York, USA; Lima, Peru; and Toronto, Canada. The remaining shares (89.49% of the total outstanding shares) are owned by the Colombian Ministry of Finance and Public Credit.

 

The address of the main office of Ecopetrol S.A. is Bogotá – Colombia, Carrera 13 No. 36 - 24.

 

2.Basis of presentation

 

2.1Statement of compliance and authorization of financial statements

 

These Consolidated Financial Statements of Ecopetrol S.A. for the years ended December 31, 2015 and 2014, have been prepared in accordance with International Financial Reporting Standards and Interpretations issued by the International Accounting Standards Board (IASB). The Ecopetrol Business Group adopted IFRS since January 1, 2015 with a transition date of January 1, 2014 and as such, these are its first consolidated financial statements under IFRS.

 

The Consolidated Financial Statements for the years ended December 31, 2014 and 2013 were prepared in accordance with Public Accounting Regime issued by the Contaduría General de la Nación (CGN – National Accounting Office) and other legal provisions, which were considered as previously Generally Accepted Accounting Principles (former GAAP). Former GAAP differs in certain respects from IFRS, as disclosed in Note 35 – First-time adoption of International Financial Reporting Standards - IFRS.

 

Accounting policies described in Note 4 have been applied consistently in all periods.

 

These Consolidated Financial Statements were approved by the Company’s management on April 21, 2016.

 

2.2Basis of consolidation

 

For presentation purposes, the Consolidated Financial Statements were prepared by consolidating all companies set out in Exhibit 1, which are those that Ecopetrol is able to control directly or indirectly. Control is achieved when the Company:

 

·Has power over the investee;
·Is exposed, or has the rights, to variable returns from its involvement with the investee; and
·Has the ability to use its power to affect its returns.

 

When the Company has less than a majority of the voting rights of an investee, it still has power over the investee when the voting rights are sufficient to give it the practical ability to direct the relevant activities of the investee unilaterally. The Company considers all relevant facts and circumstances in assessing whether or not the Company’s voting rights in an investee are sufficient to give it power, including:

 

·The size of the Company’s holding of voting rights relative to the size and division of holding of the other shareholders;
·Potential voting rights held by the Company, other vote holders or other parties;
·Rights arising from other contractual arrangements; and
·Any additional facts and circumstances that indicate that the Company has, or does not have, the current ability to direct the relevant activities, at the time that decisions need to be made, including voting patterns at previous shareholders´ meetings.

 

F-8 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

Subsidiaries are consolidated from the date on which control is obtained until the date that such control ceases, using consistent accounting policies.

 

All intercompany assets and liabilities, equity, income, expenses and cash flows relating to transactions between entities of the Group were eliminated on consolidation. Unrealized losses are also eliminated unless the transaction provides evidence of an impairment of the asset transferred. Non-controlling interest represents the proportion of income, other comprehensive income and net assets in subsidiaries that is not attributable to the Company’s shareholders.

 

In 2015, the Board of Directors of Ecopetrol S.A authorized the creation of a Colombian company indirectly wholly owned by Ecopetrol S.A. This Company will develop offshore activities in Colombia, which the company currently carries out as operator and non-operator, and take advantage of the benefits of Decree 2682/14, “pursuant to which the conditions and requirements are established for declaring the existence of Permanent Offshore Free Trade Zones”. At December 31, 2015, the legal proceedings were pending to formalize the establishment of the subsidiary.

 

2.3Measurement basis

 

The Consolidated Financial Statements have been prepared on a historical cost basis except for financial assets and liabilities that are measured at fair value through profit or loss and / or through other comprehensive income at the end of each reporting period, as explained in the accounting policies below.

 

Historical cost is generally based on fair value of the consideration given in exchange for goods and services.

 

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. In estimating the fair value of an asset or liability, the Group takes into account the characteristic of the asset or liability if market participants would take those characteristics into account when pricing the asset or liability at the measurement date.

 

2.4Presentation and functional currency

 

Items included in the financial statements of each of the Group’s entities are measured using the currency of the primary economic environment in which the Group entities operate (the functional currency). The consolidated financial statements are presented in Colombian Pesos, which is the Group’s presentation currency.

 

The statement of profit or loss and statement of cash flows of subsidiaries with functional currencies different from Ecopetrol’s functional currency are translated at the exchange rates at the dates of the transaction or based on the monthly average rate. Assets and liabilities are translated at the closing rate and other equity items are translated at exchange rates at the moment of the transaction. All resulting exchange differences are recognized in other comprehensive income. Upon disposal of all or part of an interest in an entity, the appropriate portion of the cumulative translation adjustment related to that entity are generally recognized in the consolidated statement of profit and loss.

 

2.5Foreign currency

 

In the preparation of the financial statements of Ecopetrol, transactions in currencies other than the entity’s functional currency are recognized at the rates of exchange prevailing at the dates of the transactions. At the end of each reporting period, monetary items denominated in foreign currencies are translated at the rates prevailing at the period end and variations presented on translation are recognized in financial results, net, except those resulting from the conversion of loans and borrowings designated as cash flow hedges, which are recognized in other comprehensive income within equity. When the hedged item affects the results, exchange differences accumulated in equity are reclassified to the Consolidate statement of profit and loss as part of the operational result.

 

Non-monetary items carried at fair value that are denominated in foreign currencies are translated using the rates prevailing at the date when the fair value was determined.

 

Net investment in foreign operations includes equity financing and long-term intercompany loans for which settlement is neither planned nor likely to occur in the foreseeable future. Exchange rate differences arising from the translation of the net investment in foreign operations, are taken to the currency translation reserve in other comprehensive income.

 

2.6Classification of assets and liabilities as current and non-current assets and liabilities

 

In the consolidated statement of financial position, assets and liabilities are classified according to their nature as current, being those with a maturity date equal to or less than twelve months; and non-current, being those with a maturity date greater than twelve months.

 

F-9 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

2.7Net earnings per share (basic and diluted)

 

Net earnings per share (basic and diluted) are calculated based on net earnings for the period attributable to the controlling stockholders, divided by the weighted average number of subscribed shares in circulation during the period. There are no potentially dilutive securities.

 

3.Significant accounting judgments and estimations

 

The preparation of financial statements requires that the Company’s management make estimations about the carrying amounts of assets, liabilities, income, expenses and commitments recognized in the Financial Statements. These estimations are carried out based on the best available information on the matters under review. Revisions to accounting estimates are recognized prospectively in the period in which the estimation is revised.

 

The following are the critical judgments and estimations with most significant effect on the amounts recognized in the Consolidated Financial Statements:

 

3.1Oil and Gas reserves

 

Measurements relating to depreciation, depletion, amortization, impairment and asset retirement obligation are determined, in part, based on the Company's estimated reserves of oil and natural gas. Reserves estimation is an inherently complex process and it involves professional judgments.

 

The reserves estimation is conducted annually at December 31 in accordance with the United States Securities and Exchange Commission (SEC) definitions and rules set forth in Rule 4-10(a) of SEC Regulation S-X and the disclosure guidelines contained in the SEC final rule - Modernization of Oil and Gas Reporting.

 

The estimated reserve amounts are based on the average prices during the 12-month period prior to the ending date of the period covered in the report, determined as the unweighted arithmetic averages of the prices in effect on the first-day-of-the-month for each month within such period, unless prices were defined by contractual arrangements, as required by the SEC regulations.

 

Reserves estimations are prepared using geological, technical and economic factors, including projections of future production rates, oil prices, engineering data and length and amount of future investments with a certain degree of uncertainty. These estimations which are based on conditions in existence at the reporting date, which, in turn, could significantly differ from other conditions during the year or in future periods. Any changes in regulatory and/or market conditions and assumptions could materially change the quantity and value of our reserves.

 

Impact of oil reserves and natural gas in depreciation and depletion

 

Changes to estimations of reserves are applied prospectively to the amounts of depreciation, depletion and amortization charged and, consequently, the carrying amounts of exploration and production assets. Therefore all other variables being equal, a decrease in estimated proved reserves would increase, prospectively, depreciation, depletion and amortization expense, while an increase in reserves would reduce depreciation, depletion and amortization.

 

Information about the carrying amounts of exploration and production assets and the amounts charged to income, including depreciation, depletion and amortization, is presented in Notes 15 and 16.

 

3.2Asset impairment

 

The Company uses its professional judgment in assessing the existence of evidence of impairment, based on internal and external factors. The recoverable amount for Cash Generating Units is calculated using reasonable assumptions regarding: (1) estimation of the volumes and market value of oil and natural gas reserves; (2) production profiles for oilfields and future production of refined and chemical products; (3) investments, taxes and future costs; (4) useful life of assets; (5) future prices, and (6) discount rate determined as the weighted average cost of capital (WACC), among other factors. Once the recoverable amount has been determined (value in use), it is compared with the net book value of the asset, thus determining whether the asset is subject to the recognition of impairment.

 

F-10 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

Future price assumptions tend to be stable because management does not consider short-term increases or decreases in prices as being indicative of long-term levels, but they are nonetheless subject to change. Expected production volumes, which comprise proved reserves and unproved volumes, are used for impairment testing because management believes this to be the most appropriate indicator of expected future cash flows. Reserves estimates are inherently imprecise. Furthermore, projections about unproved volumes are based on information that is necessarily less robust than that available for mature reservoirs. The discount rate applied is reviewed annually.

 

Changes in estimates and judgments may affect the recoverable amount for the Cash Generating Units and, as a consequence, may also affect the recognition or recovery of asset impairment.

 

3.3Exploration and Evaluation Cost

 

Certain exploration and evaluation costs are initially capitalized with the intention of establishing commercially viable reserves. The Company makes estimates in order to assess the economic viability of extracting the oil resources, as well as technical and commercial analyses to confirm intent in terms of projects' continued implementation. Changes regarding drilling success level, production costs, investment levels, and others, may result in capitalized exploration drilling costs being recognized as a cost in the Consolidated Statement of Profit and Loss for the period. Dry holes are treated like operating activities in the cash flow.

 

3.4Determination of Cash Generating Units

 

The allocation of assets in Cash Generating Units requires significant judgment on the part of the Company, as well as interpretations regarding the integration between assets, the existence of active markets, similar exposure to market risk, shared infrastructure, and the way in which management monitors the operations. See note 4.12 for more information.

 

3.5Asset Retirement Obligation

 

According to environmental and oil regulations, the Ecopetrol Business Group must recognize costs for the abandonment of oil extraction and transportation facilities, which include the cost of plugging and abandoning wells, dismantling facilities and environmental remediation in the affected areas.

 

The estimated costs of dismantling and removing these facilities are recorded in the functional currency of each company at the time of the installation of the assets. The estimated obligations created for the abandonment and dismantling are subject to annual reviews and adjusted to reflect the best available estimation, due to technological changes and political, economic, environmental and security issues, and also relationships with stakeholders.

 

The calculations of these estimations are complex and involve significant judgments made by Management, such as internal projections of costs, future inflation and discount rates. We consider that the retirement costs and obligations are reasonable, based on the experience of the Ecopetrol Business Group and market conditions; nevertheless, significant variations in external factors used for the calculation of the estimation could significantly impact the financial statements.

 

3.6Pension Plan and other benefits

 

The identification of expenses, liabilities and adjustments relating to pension plans and other defined retirement benefits makes it necessary for management to use judgment in the application of actuarial assumptions. The actuarial assumptions include estimates regarding future mortality, retirement, changes in compensation and discount rate in order to reflect the value of money over time, in addition to the rate of return on the plan's assets. These assumptions are reviewed on an annual basis for purposes of actuarial valuations and may differ materially from actual results due to changing economic and market conditions, regulatory events, judicial rulings, higher or lower retirement rates, or longer or shorter life expectancies among employees. The calculation of pension bonds is maintained for compliance with the Company's pension obligations, in accordance with current regulations.

 

3.7Goodwill Impairment

 

Ecopetrol performs annual impairment tests of goodwill in reference to fair value. Goodwill, for impairment testing purposes, is allocated to each of the cash-generating units (or groups of cash generating units) that is expected to be benefited from the synergies of the combination.

 

Fair value is determined using the discounted free cash flow methodology that requires assumptions and estimations to be made. The Company considers that the assumptions and estimations used are reasonable and supportable based on the current market conditions and are aligned to the risk profile of the related assets. However, different assumptions and estimations may be used which would lead to different results. Valuation models used to determine fair value are sensitive to changes in the underlying assumptions. For example, sales volumes and prices that will be paid for the purchase of raw materials are assumptions that may vary in the future. Adverse changes in any of these assumptions could lead to recognition of goodwill impairment.

 

F-11 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

3.8Litigation Assessments

 

The Company is subject to claims for regulatory and arbitration proceedings, tax assessments and other claims arising in the normal course of business. Management evaluates these situations based on their nature, the likelihood that they materialize, and the amounts involved, to decide on any changes to the amounts accrued and/or disclosed. This analysis, which may require considerable judgment, includes assessment of current legal proceedings brought against us and claims not yet initiated. In accordance with management’s evaluation and guidance provided by IFRS, we create provisions to meet these costs when the liability is probable and reasonable estimations of the liability can be made.

 

3.9Taxes

 

Calculation of the income tax provision requires interpretation of tax law in the jurisdictions where the business group operates. Significant judgment is required to determine estimates for income tax and to evaluate the recoverability of tax assets, which are based on estimates of future tax results and the ability to generate sufficient results during the periods in which such deferred taxes are deductible.

 

If future cash flows and taxable income differ significantly from estimates, the Company's ability to use the net deferred tax assets recorded at the reporting date could be affected. In addition, changes to tax laws could limit the Company's ability to obtain tax deductions in future periods.

 

3.10Hedge Accounting

 

The process of identifying hedging relationships between hedging items and instruments (derivative and non-derivative, e.g. long-term foreign currency debt) and their corresponding effectiveness requires management’s judgment. The Company regularly evaluates the alignment between the hedging identified and its risk management policy.

 

4.Accounting policies

 

The accounting policies indicated below have been applied consistently for all the periods presented, unless otherwise stated.

 

4.1Financial instruments

 

The classification of financial instruments depends on the nature and purpose for which the financial assets or liabilities were acquired and is determined at the time of initial recognition. Financial assets and financial liabilities are initially measured at their fair value. Transaction costs that are directly attributable to the acquisition or issue of financial assets and financial liabilities (other than financial assets and financial liabilities at fair value through profit or loss) are added to or deducted from the fair value of the financial assets or financial liabilities, as appropriate, on initial recognition. Transaction costs directly attributable to the acquisition of financial assets or financial liabilities at fair value through profit or loss are recognized immediately in profit or loss.

 

Financial assets through profit or loss and through other comprehensive income are stated at fair value. Financial instruments at amortized cost, loans and trade receivables, other receivables and financial assets held-to-maturity are measured at amortized cost using the effective interest method.

 

Equity investments available for sale that do not have a market quotation price and which fair value cannot be reliably measured are measured at cost less any loss for impairment identified at the end of each reporting period.

 

Fair value

 

Fair value measurements are estimates of the amounts for which assets or liabilities could be transferred at the measurement date, based on the assumption that such transfers take place between participants in principal markets and, where applicable, taking highest and best use into account.

 

The fair value hierarchy is based on the level of market available information which includes the security liquidity and availability of exchange prices or indicators generated from market operations (rates, curves, volatilities and other required valuation variables).

 

·Level 1: Quoted prices (unadjusted) in active markets for identical assets and liabilities. For the Company, level-1 inputs include marketable securities that are actively traded.

 

F-12 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

·Level 2: Entries different from those of Level 1 that are observable, either directly or indirectly. For the Company, Level-2 entries include prices of similar assets, prices obtained through quotations made by stockbrokers, and prices that can be substantially corroborated with other observable data with the same term of the contract.

 

·Level 3: Unobservable inputs. Level-3 inputs may be required for the determination of fair value associated with certain non-recurring measurements of non-financial assets and liabilities.

 

For derivative contracts where publicly available information is not available, fair value estimations are generally determined using models and other valuation methods, the key inputs for which include future prices, volatility, price correlation, counterparty credit risk and market liquidity, as appropriate; for other assets and liabilities, fair value estimations are generally based on the net present value of expected future cash flows.

 

Effective interest method

 

The effective interest method is a method of calculating the amortized cost of a financial instrument and of allocating interest income over the relevant period. The effective interest rate is the rate that exactly discounts estimated future cash receipts or payments (including all fees, transaction costs and other premiums or discounts that are included in the calculation of the effective interest rate) through the expected life of the financial instrument (or, when appropriate, at a shorter period), to the net carrying amount on initial recognition.

 

Impairment

 

Financial assets at amortized cost are assessed for impairment indicators at the end of each reporting period. Financial assets are considered to be impaired when there is objective evidence that, as a result of one or more events that occurred after initial recognition, the estimated future cash flows of the asset have been affected. For financial assets measured at amortized cost, the amount of the impairment loss recognized is the difference between the asset’s carrying amount and the present value of estimated future cash flows, discounted at the financial asset’s original effective interest rate.

 

De-recognition of financial assets and financial liabilities

 

Ecopetrol derecognizes a financial asset when the contractual rights to the cash flows from the asset expire and when it transfers substantially all the risks and rewards of ownership of the asset to another party. If neither the risks nor rewards of ownership are transferred and the Company continues to control the transferred asset, its retained interest in the asset and any associated liability for amounts it may have to pay continue to be recognized. If all the risks and rewards of ownership of a transferred financial asset are retained, the financial asset and any collateralized borrowing for the proceeds received are recognized.

 

4.1.1Cash and cash equivalents

 

Cash and cash equivalents include financial investments and special funds with original maturity dates of 90 days or less from their acquisition and are subject to minimal risks of changes in value.

 

4.1.2Financial assets

 

The classification of investments in financial assets depends on the purpose of acquisition; those are classified in the following categories:

 

a)Financial assets at fair value through profit or loss

 

Financial assets at fair value through profit or loss are financial assets held for trading acquired mainly for the purpose of selling them in the short term. Financial assets at fair value through profit or loss are stated at fair value, with any gains or losses arising on re-measurement recognized in profit or loss.

 

b)Financial assets at fair value through other comprehensive income

 

Financial assets at fair value through other comprehensive income are equity instruments of other non-controlled or non-strategic companies where the Company does not exercise any type of control or significant influence thereon and where the Company does not intend to sell the instruments in the short term. They are recognized at their fair value and unrealized losses or profits are recognized in other comprehensive income. At the time of sale or impairment of the assets the related adjustments for valuation are attributed to the results of the period.

 

F-13 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

c)Loans and receivables

 

Loans and receivables are financial assets with fixed or determinable payments that are not quoted in an active market are classified as current, except for those that have a maturity date longer than twelve months from the statement of financial position date, which are classified as non-current. Loans and receivables, including trade and other receivables, are measured initially at fair value and then at amortized cost using the effective interest rate method.

 

Loans to employees are initially recognized using the present value of the future cash flows, discounted at the current market rate of return for similar loans. If the interest rate is less than the current market rate, fair value will be less than the amount of the loan. This difference is recorded as a benefit to employees.

 

4.1.3Financial liabilities

 

Financial liabilities correspond to the financing obtained by the Company through bank credit facilities and bonds, accounts payable to suppliers and creditors.

 

Bank credit facilities and bonds are initially recognized at their fair value, net of transactions costs incurred. The difference between the amount received and its nominal value is recognized in the results of the period during the time of amortization of the financial obligation, using the effective interest rate method.

 

Accounts payable to suppliers and creditors are short term financial liabilities recorded at their fair value, since they do not differ significantly from their fair value.

 

4.1.4Derivative financial instruments and hedging activities

 

Financial derivatives instruments are recognized in the statement of financial position as assets or liabilities and are measured at fair value from the date when the derivative is contracted. The method of recognizing the resulting gain or loss depends on whether the derivative is designated as a hedging instrument, and if so, the nature of the item being hedged.

 

The Company designates certain financial instruments derivatives and non-derivatives as hedges, with respect to the risk to be covered such us:

 

-hedges of the fair value, when it involves a hedging the exposure to changes in fair value of a recognized asset or liability, unrecognized firm commitments, or an identifiable portion of such assets, liabilities or firm commitments.

 

-Cash flow hedges when it involves a hedging of the exposure to variability in cash flows that is attributable to a particular risk associated with a recognized asset or liability or a highly probable forecast transaction.

 

-Hedges of a net investment in a foreign operation.

 

At the beginning of the hedging relationship, the Company documents the relationship between the hedging instrument and the hedged element, together with their risk management objectives and their strategy to carry out hedging transactions. Additionally, at the beginning of hedging and on a continuous basis, the Company documents whether the hedging instrument is highly effective in counteracting the changes in fair values or cash flows of the items hedged.

 

The fair value of a hedging derivative is classified as a non-current asset or liability when the remaining maturity of the hedged item is more than 12 months and as a current asset or liability when the remaining maturity of the hedged item is less than 12 months.

 

Gains and losses on derivative contracts not qualifying and designated as hedges, including forward sale and purchase contracts for commodities in trading operations that may be settled by the physical delivery or receipt of the commodity, are recognized in income.

 

Derivatives embedded within contracts that are not already required to be recognized at fair value, and that are not closely related to the host contract in terms of economic characteristics and risks, are separated from their host contract and recognized at fair value; associated gains and losses are recognized in income.

 

F-14 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

4.1.4.1Cash flow hedges

 

The effective portion of changes in the fair value of derivative and non-derivative financial instruments that are designate and qualify as an effective cash flow hedges, is recognized in other comprehensive income and accumulated under the heading reserve. A gain or loss relating to the ineffective portion is recognized immediately in profit or loss, and is included in the “Finance Results, net” line item.

 

Amounts previously recognized in other comprehensive income and accumulated in equity are reclassified to profit or loss in the periods when the hedged item affects profit or loss, in the same line as the recognized hedged item. However, when the hedged forecast transaction results in the recognition of a non-financial item, the gains and losses previously recognized in the other comprehensive income and accumulated in equity are transferred from equity and included in the initial measurement of the cost of the non-financial item.

 

Hedge accounting is discontinued when the Company revokes the hedging relationship, when the hedging instrument expires or is sold, finished, or exercised, or when it no longer qualifies for hedge accounting. Any gain or loss recognized in other comprehensive income and accumulated in equity remains in equity and is recognized when the forecast transaction is ultimately recognized in profit or loss. When a forecast transaction is no longer expected to occur, the gain or loss accumulated in equity is recognized immediately in profit or loss.

 

4.2Inventories

 

Inventories include assets extracted, in production process, transformed or acquired for any reason, for the purpose of being sold, transformed and consumed in the production process, or as part of services delivered.

 

Crude oil is valued at its production cost, including necessary expenses incurred to transport the inventory to its current locations.

 

Inventories of consumables (spare parts and supplies) are recognized as inventory and subsequently charged to expense, maintenance or projects, as such elements are consumed.

 

The cost of inventories is determined under the weighted average method, which includes acquisition costs (deducting commercial discounts, rebates obtained and other similar amounts), transformation, as well as other costs incurred in order to deliver the inventories to their current location and conditions, such as transportation costs.

 

Ecopetrol makes an evaluation of the net realizable value of inventories at the end of the period, recording, with charge to profit and loss, impairment to the value when they are overvalued. When the circumstances that previously caused impairment cease to exist, or when there is clear evidence of an increase in the net realizable value due to a change in economic circumstances, the amount thereof is then reversed.

 

4.3Related parties

 

For purposes of these consolidated financial statements, related parties are considered those in which one party has the ability to control, or joint control the other or exercise significant influence over the other party in making financial or operational decisions, or is a member of the key management personnel of the entity or of a parent of the entity. The Company has considered as related parties associates, joint ventures, key management and some relevant transactions with government entities, such as the purchase of hydrocarbon and the Fuel Price Stabilization Fund See Note 4.16.

 

4.3.1Investments in associates

 

An associate is an entity over which the Group has significant influence but not control. Generally, these entities are those in which an equity interest is maintained from 20% to 50% of the voting rights. See Exhibit I - Consolidated companies, associates and joint ventures for a detail of these companies.

 

Investments in associates are accounted for using the equity method and are initially recognized at their cost. The Company's investment in associates and joint ventures includes goodwill identified on acquisition, net of any accumulated impairment loss.

 

The Company's share of the profit or loss of its associates is recognized in the consolidated statement of profit or loss and its share of reserve movements is recognized in the Company equity reserves.

 

Ecopetrol makes, where necessary, adjustments to the accounting policies of associates and joint ventures to ensure consistency with the policies adopted by the Company.

 

F-15 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

4.3.2Joint ventures

 

A joint venture is a joint arrangement whereby the parties that have joint control of the arrangement have rights to the net assets of the joint arrangement. Joint control exists only when decisions about the relevant activities require unanimous consent of the parties sharing such control. The accounting treatment for the recognition of joint ventures is the same as investments in associates.

 

4.4Joint operations

 

Joint operation contracts are entered into between Ecopetrol and third parties in order to share risk, secure capital, maximize operating efficiency and optimize the recovery of reserves. In these joint operations, one party is designated as the operator to execute the expense and investment budget and report to partners according to their participation interests. Furthermore, each party takes its share of the hydrocarbons (crude oil or gas) produced according to its agreed participation.

 

When Ecopetrol participates as a non-operator partner, it records the assets, liabilities, revenues, costs and expenses based on information reported by the operators. When Ecopetrol is the direct operator of the joint venture contracts, it records its percentage of the assets, liabilities, revenues, costs and expenses, based on each partner’s participation interests in the accounts corresponding to assets, liabilities, expenses, costs and revenues.

 

4.5Non-current assets held for sale

 

Non-current assets and disposals groups are classified as held for sale if their carrying amount will be recovered principally through a sale transaction rather than through continued use. This condition is regarded as met only when the sale is expected to qualify for recognition as a completed sale within one year from the date of classification and the asset (or disposal group) is available for immediate sale in its present condition. These assets are measured at the lower of their carrying amount and fair value less cost to sell.

 

4.6Property, plant and equipment

 

Recognition and measurement

 

Property, plant and equipment are presented at cost less accumulated depreciation and accumulated losses for impairment. Tangible components related to natural and environmental resources are part of property, plant and equipment.

 

All directly attributable costs of bringing an asset to the location and condition needed for such issue to be capable of operating in the manner intended by management are capitalized. Such costs are mainly: a) purchase price, including import duties and non-refundable purchase taxes; b) costs of employee benefits arising directly from the construction or acquisition; c) all directly attributable costs of bringing the asset to the location and conditions needed for such issue to be capable of operating in the manner intended by management; d) borrowing costs incurred that are attributable to the acquisition and construction of qualifying assets and; e) the initial estimate of the costs of dismantling and abandonment of the item.

 

Spare parts and servicing equipment are recorded as inventories and recognized as an expense as they are used. Major spare parts and stand-by equipment that the entity expects to use during more than one period are recognized as property, plant and equipment.

 

Any gain or loss arising from the disposal of a property, plant and equipment item is recognized in profit or loss in the period incurred.

 

Subsequent disbursements

 

They correspond to all payments to be made on existing assets in order to increase or extend the initial expected useful life, increase productivity or productive efficiency, that allow a significant reduction of operating costs, increase the level of reserves in exploration or production areas or replace a part or component of an asset that is considered critical for the operation.

 

The costs of the day-to-day servicing, repair or maintenance of an item of property, plant and equipment are recognized as expense when incurred. However, major inspections performed, are capitalized.

 

Depreciation

 

Property, plant and equipment is depreciated using the straight-line method, except for those associated with Exploration and Production activities which are depreciated using the units-of-production method. Technical useful lives are updated annually considering factors such as: additions or improvements (due to parts replacement or critical components for the asset’s operation), technological advances, obsolescence and other factors; the effect of this change is recognized from the period in which it was executed. Depreciation of an asset arises when it is available for use.

 

F-16 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

Useful lives are determined based on the period over which an asset is expected to be available for use, physical exhaustion, technical or commercial obsolescence and legal limits or restrictions over the use of the asset.

 

Plant and equipment 7 - 56 years
Pipelines, networks and lines 10 - 53 years
Buildings 19 - 72 years
Others 3 - 38 years

 

Lands are recorded independently of buildings and facilities and have indefinite useful lives therefore they are not subject to depreciation.

 

Depreciation methods and useful lives are reviewed annually by business units and adjusted if appropriate.

 

4.7Natural and environmental resources

 

Recognition and measurement

 

Ecopetrol uses the successful efforts method to account for exploration and production of crude oil and gas activities, also considering IFRS 6 – Exploration for the evaluation of mineral resources.

 

Exploration costs

 

All costs associated with exploration and evaluations are recorded as exploration and evaluation assets pending on determination of whether the exploration drilling is successful or not; if determined to be unsuccessful all costs are recognized as expenses in the Statement of Profit or Loss.

 

Exploration costs are those incurred with the objective of identifying areas that are considered to have prospects of containing oil and gas reserves, including geological and geophysical, seismic costs, exploratory wells, exploratory-type stratigraphic test wells, among others. Exploratory wells costs are recognized as assets pending on determination of commercial viability and if not, they are recognized as exploration expenses. Other expenditures are recognized as expenses when incurred.

 

An asset for exploration and evaluation shall no longer be classified as such whenever the technical reliability and the commercial viability of extraction of a mineral resource are demonstrable. Before reclassification, assets are assessed for impairment, and any resulting impairment is recognized. Exploration and evaluation assets are assessed for impairment when facts and circumstances suggest its carrying value is lower than its recoverable value.

 

Development costs

 

Development costs correspond to those costs incurred to obtain access to test hydrocarbon reserves and to provide facilities for extracting, treating, gathering and storing. When a project is approved for development, the accumulated value of the acquisition and exploration costs is classified as natural and environmental resources and costs subsequent to the exploration phase are capitalized as development costs of the properties that contain such natural resources assets. All development costs are capitalized, including drilling costs of unsuccessful development wells.

 

Production costs

 

Production costs are those incurred to operate and maintain productive wells as well as the corresponding equipment and facilities. The production activity includes extraction of oil and gas to the surface, its gathering, treatment and processing as well as storage in the field. Production costs are expenses at the time they are incurred unless they add reserves, in which case they are capitalized.

 

Production and support equipment is recognized at historical cost and is part of property, plant and equipment and subject to depreciation.

 

Capitalized costs also include dismantlement, retiring and restoring costs, as well as the estimated cost of future environmental obligations. The estimation includes plugging and abandonment costs, facility dismantling and environmental recovery of areas and wells. Changes arising in new abandonment liability estimations and environmental remediation are capitalized to the related asset.

 

F-17 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

Capitalized costs include net income obtained by the sale of crude oil from extensive testing, net of cost of sales, since they are considered necessary to complete the asset.

 

Depletion

 

Depletion of natural and environmental resources is determined using the unit-of-production method per field, using proved developed reserves as a base. Depletion factors are reviewed annually, based on the reserve report and the impact of changes of such factors on the depletion is recognized prospectively in the financial statements.

 

Reserves are audited by internationally recognized external consultants and approved by the Company’s Board of Directors. Proved reserves consist of the estimated quantities of crude oil and natural gas demonstrated with reasonable certainty by geological and engineering data to be recoverable in future years from known reserves under existing economic and operating conditions, that is, at the prices and costs that apply at the date of the estimation.

 

Impairment

 

Assets associated to exploration, evaluation and production are subject to review for possible impairment in their recoverable value. See policy 4.12 – Impairment of assets.

 

4.8Capitalization of borrowing costs

 

Borrowing costs related to the acquisition, construction or production of a qualifying asset that requires a substantial period of time to get ready for its intended use are capitalized as part of the cost of such asset when it is probable that future economic benefits associated with the item will flow to the Company and costs can be measured reliably. The other borrowing costs are recognized as finance costs in the period in which they are incurred.

 

4.9Intangible assets

 

Intangible assets with finite useful lives that are acquired separately are recorded at their cost less accumulated amortization and accumulated impairment losses. Amortization is recognized on a straight-line basis over their estimated useful lives. The estimated useful life and amortization method are reviewed at the end of each reporting period, with the effect of any changes in estimations being accounted for prospectively.

 

Disbursements for research activities are recognized as an expense in the period in which they are incurred.

 

4.10Goodwill

 

Goodwill is the excess of the purchase price over the fair value of the identifiable assets and liabilities of acquired companies, measured at the acquisition date. The carrying amount of goodwill is not amortized and is reviewed at least annually for possible impairment losses or when there is an indication that the asset could be impaired.

 

4.11Leases

 

Leases are classified as finance leases whenever the terms of the lease transfer substantially all the risks and rewards of ownership. All other leases are classified as operating leases.

 

Assets held under finance leases, when Ecopetrol is the lessee, are recognized in the statement of financial position at an amount equal to the fair value of the leased asset or, if lower, the present value of the minimum lease payment. The corresponding liability to the lessor is included in the consolidated statement of financial position as a finance lease obligation.

 

Lease payments are allocated between finance expenses and reduction of the lease obligation so as to achieve a constant rate of interest on the remaining balance of the liability. Interest expenses are recognized immediately in the statement of profit or loss.

 

Operating lease payments are recognized as an expense on a straight-line basis over the lease term, except where another systematic basis is more representative of the time pattern in which economic benefits from the leased asset are consumed. Contingent rentals arising under operating leases are recognized as an expense in the period in which they are incurred.

 

F-18 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

4.12Impairment of assets

 

In order to evaluate the recoverable amount of tangible and intangible assets, Ecopetrol compares the carrying amount with its recoverable amount at the end of each reporting period or earlier, if there is any indicator that an asset may be impaired.

 

In order to make an impairment analysis, the assets are grouped into cash generating units (CGU), provided that those assets individually considered do not generate cash inflows that, to a greater extent, are independent from those generated by other assets or CGUs. The group of assets in different CGUs requires the exercise of professional judgment and the consideration, among other parameters, of the business segments. In this sense, in the segment of Exploration and Production, each CGU corresponds to each one of the different contractual areas commonly called “fields”; by exception, in those cases in which the cash inflows generated by several fields are interdependent on each other, those fields are grouped into a single CGU. In the case of the Refining and Petrochemicals segment, the CGU´s correspond to each one of the refineries of the group and for the segment of Transportation each pipeline is taken as an independent CGU.

 

The recoverable value is the higher of the fair value less costs of sale and value in use. If the recoverable amount of an asset (or of a CGU) is lower than its net carrying amount, such amount (or that of the CGU) is reduced to its recoverable amount, recognizing a loss for impairment of value as expense.

 

The value in use is determined as the sum of the future discounted cash flows adjusted to the estimated risk. The estimations of future cash flows used in the evaluation of impairment of assets are made with projections of commodity prices, supply and demand estimations and the margins of the products. In case of assets or cash generating units engaged in the evaluation and exploration of reserves, proved, probable and possible reserves are considered, with a risk factor associated to them also being considered.

 

Once a loss for impairment of value has been recorded, future amortization expense is calculated on the basis of the adjusted recoverable value.

 

Impairment losses may be reversed, except those corresponding to goodwill, only if the reversal is related to a change in estimations used after the loss for impairment was recognized. These reversals shall not exceed the carrying amount of the assets net of depreciation or amortization that would have been determined if the impairment had never been recognized.

 

In the reclassification of any non-current asset to non-current assets held-for-sale, the carrying amount of these assets is revised to its fair value less costs of sale. No other provision for depreciation, depletion or amortization is recorded if the fair value less costs of sale is lower than the carrying amount.

 

4.13Provisions and Contingent Liabilities

 

Provisions are recognized when Ecopetrol has a current obligation (legal or implied) as a result of a past event, it is probable that Ecopetrol will be required to settle the obligation, and a reliable estimation can be made of the amount of the obligation. Where applicable, they are recorded at present value.

 

Disbursements related to the conservation of the environment for current or future operations, are accounted for as expenses or assets, as it may correspond. Disbursements related to operations of the past that do not contribute to the obtaining of current or future income, are charged to expenses.

 

The creation of these provisions coincides with the identification of an obligation related to environmental remediation and Ecopetrol has adequate information to determine a reasonable estimation of the respective cost.

 

Contingent liabilities are not recognized but are subject to disclosure in the explanatory notes whenever the outlay of resources is possible; including those which values cannot be estimated.

 

Asset retirement obligation

 

Liabilities associated to the retirement of assets are recognized when there are current obligations, either legal or implied, related to the abandonment and reclamation of wells, facilities, pipelines, buildings and equipment, as the case may be; they must be recognized using the discounted cash flow technique taking into consideration the economic limit of the field or useful life of the respective asset. When it is not possible to determine a reliable estimation in the period in which the obligation originates, a provision is recognized when there is sufficient information available to make the best estimation.

 

The carrying amount of the provision is reviewed and adjusted annually considering changes in the variables used for its estimation. The financial cost of accreting these liabilities is recognized in results for the period as financial expense.

 

F-19 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

4.14Taxes

 

Income tax expense is comprised of income tax payable for the period (including, income tax and income tax for equality - CREE, as appropriate) and the effect of deferred taxes in each period.

 

Income taxes are recognized in income except when they relate to items recognized in other comprehensive income, in which case the tax is recognized in other comprehensive income. Income tax assets and liabilities are presented separately in the Consolidated Statement of Financial Position except where there is a right of set-off within fiscal jurisdictions and an intention to settle such balances on a net basis.

 

4.14.1Current tax

 

The provision for income tax and income tax for equality (CREE), as appropriate, is calculated based on the highest amount of the taxable income and presumptive income (the minimum estimated amount of profitability on which the law expects to quantify and collect the income tax). Tax profit differs from profit before tax as reported in the consolidated statement of profit or loss, because of items income or expense that are taxable or deductible in other periods, special taxable deductions, tax losses and income or expenses that are non-taxable or non-deductible according to the applicable tax laws in each jurisdiction.

 

4.14.2Deferred taxes

 

Deferred tax is accounted for according to the liability method. Deferred tax assets and liabilities are recognized for future tax consequences attributable to differences between the carrying amounts of existing assets and liabilities in the Consolidated Financial Statements and their respective tax bases. A deferred tax liability is recognized for all taxable temporary differences. A deferred tax asset is recognized for all deductible temporary differences and for all tax losses to be utilized, insofar there is a reasonable expectation that such differences will be offset against tax profits.

 

Deferred taxes on assets and liabilities are calculated based on enacted or substantively enacted statutory tax rates that we believe will be applied to taxable income during the years in which temporary differences between the carrying amounts and tax bases are expected to be reversed

 

The carrying amount of a deferred tax asset is subject to review at the end of each reporting period and it is reduced to the extent it is estimated probable that there will not be enough future taxable profit that allows the total or partial recovery of the asset.

 

Consolidated deferred tax, is calculated as the sum of the deferred tax in the individual financial statements of the companies of the Ecopetrol Business Group adjusted by deferred taxes on business combinations, intercompany transactions or other adjustments at a consolidated level.

 

Deferred taxes are not recognized when they arise in the initial recognition of an asset or liability in a transaction (except in a business combination) that, at the time of the transaction, does not affect the accounting or tax profit, or in respect of the taxes on the possible future distribution of accumulated profits of subsidiaries or investments accounted for by the equity method, if at the time of the distribution it may be controlled by Ecopetrol S.A. and it is probable that the retained earnings will be reinvested by the Group companies and therefore, will not be distributed to Ecopetrol S.A.

 

4.15Employee benefits

 

Salaries and benefits for Ecopetrol staff are governed by the Collective Labor Agreement 01 of 1977, and in their absence, by the Substantive Labor Code. In addition to the legally mandated benefits, employees are entitled to fringe benefits which are subject to the place of work, type of work, length of service, and basic salary. An annual interest of 12% is recognized on accumulated severance amounts for each employee, and the payment of compensations is provided for when special circumstances arise resulting in the non-voluntary termination of the contract, without just cause, and in periods other than the probationary period.

 

Ecopetrol S.A. belonged to the Special Pension Regime, under which allowances are a Company’s responsibility and not a Pension Fund’s responsibility. However, Act 797 of January 29, 2003 determined that Ecopetrol employees who joined the Company at that date would be subject to the provisions of the General Pension Regime. Consequently, allowances for employees retired at July 31, 2010 are still Ecopetrol’s responsibility. Likewise, these employees are entitled to such pension bonus if they worked with Ecopetrol prior to January 29, 2003, but whose labor agreement expired without renewal before that date.

 

F-20 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

All social benefits of employees who joined the Company before 1990 are Ecopetrol’s responsibility, without the involvement of any social security entity or institution. The cost of health services for the employee and his/her relatives registered with the Company is determined by means of a mortality table, prepared based on facts occurring during the year.

 

For employees who joined the Company subsequent to the entry into effect of Act 50 of 1990, the Company makes periodic contributions for severance payments, pensions and occupational injuries to the funds created for these respective obligations.

 

In 2008, Ecopetrol S.A. partially commuted the value corresponding to monthly pension payments from its pension liabilities, transferring such liabilities and their underlying amounts to pension-related autonomous equities (PAP, by its acronym in Spanish). The funds transferred, and returns on those funds, cannot be redirected nor can they be returned to the Company until all of the pension obligations have been fulfilled. The commuted obligation covers allowances and pension bonds payments; while health and education remains under the labor liability in charge of Ecopetrol.

 

Employee-benefits are divided into four groups comprised as follows:

 

a)Short-term employee benefits and post-employment benefits:

 

Benefits to employees in the short term mainly correspond to those which payment will be made in the term of twelve months following to the closing of the period in which the employees have rendered their services. This mainly includes salaries, severances, vacations, bonuses and other benefits.

 

Post-employment benefits of defined contributions correspond to the periodic payments for severances, pensions and professional risk payments that the Company makes to the respective funds that assume these obligations in their entirety.

 

The above benefits are recognized as an expense with an associated liability after deducting any already paid amounts.

 

b)Post-employment defined benefit plans:

 

In the defined benefits plan, the Company provides the benefits agreed to current and former employees and assumes the actuarial and investment risks.

 

The following benefits are classified as long-term defined benefit plans recognized in the financial statements according to the valuations made annually by an independent actuaries:

 

·  Pensions.

·  Health care to relatives.

·  Pension bonds.

·  Educational plan.

·  Retroactive severances.

 

The liabilities or assets recognized in the statement of financial position in respect of these benefit plans are the present value of the defined benefit obligation at the date of the statement of financial position, less the fair value of plan assets.

 

The defined benefit obligation is calculated annually by independent actuaries using the projected credit unit method, which takes into account employees’ years of service and, for pensions, average or final pensionable remuneration, and are discounted to their present value using interest rates of high-quality corporate bonds denominated in the currency in which the benefits will be paid and of a duration consistent with the plan obligations.

 

The amounts recognized in income in respect of defined benefit plans mainly comprise service cost and net interest. Service cost comprises principally the increase in the present value of the obligation for benefits resulting from employee service during the period (current service cost). Plan amendments are changes to benefits and are generally recognized when all legal and regulatory approvals have been received and the effects have been communicated to members. Net interest is calculated using the net defined benefit liability or asset matched against the discount rate yield curve at the beginning of each year for each plan. Remeasurements of the net defined benefit liability or asset resulting from actuarial gains and losses, the effect of the asset ceiling and the return on plan assets excluding the amount recognized in income are recognized in other comprehensive income.

 

There is no service cost for the pension plan as the beneficiaries were retired on or before July 31, 2010.

 

F-21 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

Where the plan assets exceed the gross obligation, the asset recognized is limited to the lower of the surplus in the defined benefit plan and the asset ceiling determined using a discount rate based on government bonds.

 

c)Other long-term benefits:

 

Other long-term benefit is the five-year term bonus which also forms part of the actuarial valuation. This benefit is a cash bonus which is accrued on an annual basis and is paid out at the end of each five-year period that an employee works in the Ecopetrol S.A. The Company records in the statement of profit or loss the service cost, net liability interests and adjustments to the defined benefit plan liability.

 

d)Termination benefits:

 

Termination benefits are recognized only when a detailed plan exists for such process and there is no possibility to withdraw the offer. The Company recognizes a liability and an expense for termination benefits at the earliest date between the date when the offer of such benefits cannot be withdrawn and the date when the restructuration costs are recognized.

 

4.16Revenue recognition

 

Revenue from crude oil and natural gas sales is recognized at the time of transfer of title to the buyer, including risks and rewards of ownership. In the case of refined and petrochemical products, revenue is recognized when products are shipped by the refinery and subsequently adjusted in accordance with the volumes actually delivered. Revenue from transportation services is recognized when products are transported and delivered to the buyer in accordance with sale terms. In other cases, revenue is recognized at the time it is earned and a true, probable and quantifiable right to demand its payment arises.

 

Under current regulations, Ecopetrol and Refineria de Cartagena S.A., sell regular gasoline and diesel oil at a regulated price.

 

In accordance with Decree 1068 of 2015, the Ministry of Mines and Energy semi-annually calculates and settles Ecopetrol’s net position to be stabilized for each fuel by the Fuel Price Stabilization Fund (FEPC, by its acronym in Spanish). The net position is calculated by adding all differentials throughout the six-month period and the result is an amount in Colombian pesos in favor of the Company or the FEPC and chargeable to the FEPC. The differential is calculated as the volume reported by the Company at the time of sale multiplied by the difference between the international parity price and the regulated price. The international parity price, the daily prices of gasoline and diesel oil of the respective month in Colombian pesos, are indexed to the United States of America Gulf market in accordance with Resolution 18 0522 of 2010 and the Producer Price reference defined by the Ministry of Mines and Energy.

 

4.17Cost and expenses

 

Costs and expenses are presented according to their nature; they are detailed in the related disclosures in cost of sales, and administrative, operating, projects and other associated expenses. Notes 27 and 28 present the items of cost of sales and administrative, operating and project expenses, according to their function.

 

F-22 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

5.New standards issued by the IASB

 

The standards and interpretations that are issued, but not yet effective up to the date of issuance of the company’s consolidated financial statements, and that may have an impact on the disclosures and financial position of the company, are disclosed below. The company intends to adopt these standards and interpretations, if applicable, when they become effective.

 

Standard   Description   Effective date

IFRS 9 – Financial Instruments

 

 

Includes the requirements of classification and measurement, impairment, derecognition and hedge accounting; and in relation to the impairment of financial assets, IFRS 9 requires an expected credit loss model, as opposed to an incurred credit loss model under IAS 39. Therefore, it is no longer necessary for a credit event to have occurred before credit losses are recognized.

 

The Company is currently evaluating the impact of this IFRS.

 

January 1st, 2018

         
         

IFRS 15 – Revenue from Contracts with Customers

 

 Establishes a single comprehensive model for entities to use in accounting for revenue arising from customers.

 

Under IFRS 15, an entity recognizes revenue when (or as) a performance obligation is met, i.e. when “control” of the goods or services underlying the particular performance obligation is transferred to the customer.

 

IFRS 15 will supersede the current revenue recognition guidance including IAS 18 – Revenue, IAS 11 Construction Contracts and the related interpretations when it becomes effective.

 

The Company is currently evaluating the impact of this IFRS. 

 

January 1st, 2018

         
         

 Amendments to IFRS 11 – Acquisition of an Interest in a Joint Operation

 

The IASB amended IFRS 11 in order to establish guidelines regarding accounting for the acquisition of a joint operation constituting a business.

 

The approval of this amendment could affect the Company in the event of an increase or decrease in its interest in an existing joint operation, or if it invests in a new joint operation.

 

The adoption of this amendment could impact the company in the event it increases or decreases its ownership share in an existing joint operation or invests in a new joint operation. 

 

January 1st, 2016

         
         

 Amendments to IAS 16 – Property, plant and equipment, and IAS 38 – Intangible assets

 

 Amendments clarify the accepted methods of Depreciation and Amortization and do not allow entities from using a revenue-based depreciation method for items of property, plant and equipment. The amendments introduce a rebuttable presumption that revenue is not an appropriate basis for amortization of an intangible asset.

 

The adoption of this amendments has no impact on the Company.

 

 

January 1st, 2016

 

F-23 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

 IAS 1- Presentation of Financial Statement

 

 The IASB issued amendments to IAS 1- Presentation of Financial Statements to clarify existing requirements related to materiality, order of notes, subtotals, accounting policies and disaggregation. The adoption of this amended standard is not expected to have a material impact on the company’s disclosure.

 

January 1st, 2016

         
         

IFRS- 16 Leases

 

 The IASB issued IFRS- 16 Leases which replaces the existing leasing standard (IAS 17 Leases) and requires the recognition of most leases on the balance sheet. IFRS 16 effectively removes the classification of leases as either finance or operating leases and treats all leases as finance leases for lessees with exemptions for short-term leases where the term is twelve months or less and for leases of low value items. The accounting treatment for lessors remains the same, which provides the choice of classifying a lease as either a finance or operating lease. The company is currently assessing the impact of this standard.

 

 

January 1st, 2019

Amendments to IFRS 10 – Consolidated Financial Statements

IAS 28 - Investments in Associates and Joint Venture

 

 

These amendments establish requirements for the accounting for sales or contributions of assets between an investor and its associate or joint venture. Whether or not the assets are housed in a subsidiary, a full gain or loss will be recognized in the statement of income when the transaction involves assets that constitute a business, whereas a partial gain or loss will be recognized when the transaction involves assets that do not constitute a business.

 

The Company is currently evaluating the impact of this IFRS.

 

Effective from a future date to be determined by the IASB

 

6.Cash and cash equivalents

 

The balance of cash and cash equivalents is comprised as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Banks   4,483,900    5,117,766    6,362,777 
Short-term investments   2,065,731    2,499,685    2,441,845 
Cash   819    727    468 
    6,550,450    7,618,178    8,805,090 

 

The balance for cash and cash equivalents includes resources of COP$108,348 (COP$120,545 and COP$218,848 at December 31 and January 1, 2014, respectively), mainly related to resources for the exclusive payment of principal and interest on loans incurred by Oleoducto Bicentenario S.A.S and Oleoducto de los Llanos.

 

The credit quality of cash and short-term investments is describe in Note 31.3 – Credit risk. Company funds were invested in institutions with high credit quality.

 

The fair value of cash and cash equivalents approximates its carrying amount due to its short-term nature (less than a 3-month maturity) and high liquidity.

 

7.Trade and other receivables

 

The balance of trade and other receivables is comprised as follows:

 

F-24 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Current portion               
Customers               
Foreign   1,126,511    1,718,507    2,934,134 
Domestic   1,731,547    1,261,623    1,162,197 
Fuel Price Stabilization Fund (1)   155,789    750,055    1,058,739 
Under lift   67,931    202,327    117,186 
Related parties (Note 32)   64,724    75,561    164,711 
Employee loans (2)   50,667    50,697    60,138 
Industrial services   34,987    807    13,004 
Doubtful accounts   28,042    9,304    26,944 
Others   195,256    227,976    294,386 
Total   3,455,454    4,296,857    5,831,439 
Less – Allowance for doubtful accounts (3)   (28,042)   (9,304)   (26,944)
Total current   3,427,412    4,287,553    5,804,495 
Non-current portion               
Customers               
Domestic   12,478    11,417    7,314 
Foreign   9,746    16,530    2,506 
Employee loans (2)   432,450    286,466    244,416 
Doubtful accounts   132,364    235,810    227,372 
Fuel Price Stabilization Fund (1)   77,510    77,510    77,510 
Others   52,387    43,481    24,627 
Total   716,935    671,214    583,745 
Less – Allowance for doubtful accounts (3)   (132,364)   (235,810)   (227,372)
Total Non-current   584,571    435,404    356,373 

 

(1) Account receivable from the Ministry of Finance and Public Credit, arising from the regular motor gasoline and diesel price differentials pursuant to Resolution 180522 issued on March 29, 2010. The Ministry carries out the payment in consideration of the resolution for the net liquidation position in favor of Ecopetrol for months with pending payments. During the final quarter of 2015, the Fuel Price Stabilization Fund paid COP$853,551 for the settlement of net positions in favor of Ecopetrol and the company recorded in favor an additional differential by COP$259,285 during 2015.

 

(2) The administration, management and control of loans granted to employees by Ecopetrol were transferred to Cavipetrol, who manages the details per employee of such loans and their respective conditions.

 

(3) The following shows the changes in allowance for doubtful accounts related to trade and other receivables:

 

   December 31,   December 31, 
   2015   2014 
Opening balance   245,114    254,316 
Recovery of allowances   (104,440)   (168)
Additions of allowances   30,062    2,326 
Accounts receivable write-off   (225)   - 
Uses and effects of exchange rate changes   (10,105)   (11,360)
Closing balance   160,406    245,114 

 

Carrying amounts of trade and other receivables approximates their fair value because of the short-term nature.

 

8.Inventories

 

The balance of Inventories is comprised as follows:

 

F-25 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Finished products               
Crude oil for commercialization   701,428    611,250    1,019,618 
Fuels and Petrochemicals   1,005,293    1,081,467    986,414 
Purchased products               
Crude oil   143,652    224,106    296,289 
Fuels and Petrochemicals   30,617    50,571    79,036 
Raw materials               
Crude oil for refining   220,798    174,290    255,748 
Fuels and Petrochemicals for refining   44,774    59,079    40,180 
Products in process               
Fuels and Petrochemicals   500,192    392,768    496,027 
Materials for the production of goods   609,743    488,387    486,764 
Total   3,256,497    3,081,918    3,660,076 
Less – Provision for inventories (1)   (198,539)   (151,997)   (100,490)
Total   3,057,958    2,929,921    3,559,586 

 

(1)The following shows a breakdown of the changes in the provisions for inventories:

 

   December 31,   December 31, 
   2015   2014 
Opening balance   151,997    100,490 
Additions of provision   53,205    74,683 
Foreign currency translation   13,670    6,741 
Uses   (20,333)   (29,917)
Closing balance   198,539    151,997 

 

The variation in the inventory provision is mainly due to the adjustment of inventory to its net realizable value due to the current fluctuations in international crude oil prices.

 

9.Taxes

 

9.1Current tax assets and tax liabilities

 

The balance of current tax assets and tax liabilities is comprised as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Current tax Assets               
Income tax   3,403,190    331,594    132,820 
Credit tax balance (1)   1,098,544    1,687,472    1,412,715 
Total   4,501,734    2,019,066    1,545,535 
                
Current tax Liabilities               
Income tax   2,120,398    1,238,704    1,898,946 
National tax on gasoline and surtax on gasoline   314,723    269,612    267,459 
Other taxes (2)   368,438    388,622    247,138 
Equity tax   -    -    552,927 
Total   2,803,559    1,896,938    2,966,470 

 

Income tax asset is related with prepayments made by the group companies which cannot be offset with the income tax liability because it is generated by different companies.

(1)It mainly includes a credit VAT balance.
(2)It mainly includes the balance of the Industry and Commerce Tax payable

 

F-26 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

 

9.2Income tax

 

Current tax regulations applicable to Ecopetrol establish that:

 

(a)As from January 1, 2013, income tax in Colombia, is levied at a 25% rate on the concept of income tax; at a 9% rate on the concept of income tax for equality -“CREE”, except for the taxpayers that by express regulation receive special rates; and at a 10% rate, income coming from occasional gains. Companies in the Free Trade Zone pay taxes at a 15% rate, and companies that do not generate net income or net income is less than the presumptive minimum taxable income, its income tax is rate of 3% of equity for tax purposes.

 

On December 23, 2014, Act 1739 established surtax to the income tax for equality – CREE for 2015, 2016, 2017, and 2018, and will be applicable on a taxable base higher than COP$800 million, at 5%, 6%, 8% and 9% per year, respectively.

 

The Ecopetrol group has companies pay income tax using the ordinary rate of 39%, Free Trade Zone companies that are taxed at a 15% rate, companies that pay presumptive income tax in Colombia, and others with income from abroad under rates set by other countries.

 

(b)Up to 2007, solely for tax purposes, taxpayers could annually adjust the cost of movable and immovable property representing fixed assets. The adjustment percentage will be as set by the Department of National Tax and Customs by means of a resolution.

 

(c)At December 31, 2015 and 2014, Bioenergy, Bioenergy Zona Franca and Refineria de Cartagena, which are part of the group, have tax losses amounting to a value of COP$1,524,148 and COP$1,466,326 million, respectively, originating between 2009 and 2015. According to tax regulations in force, the tax losses generated as from taxable year 2007 may be offset, fiscally readjusted, with no percentage limitation, at any time, with the net ordinary income without prejudice to the presumptive (minimum taxable) income for the period. Losses from companies shall not be transferable to the partners.

 

Tax losses with no expiry date total COP$1,524,148 (2014 - COP$1,476,566), with a deferred tax of COP$238,193 (2014 - COP$527,794) attributable to Bioenergy, Bioenergy Zona Franca and Refineria de Cartagena.

 

As from 2015, in conformity with the provisions of Act 1739 of December 2014, tax losses and excesses of minimum base may be offset with future income originated in the income tax for equality - CREE, considering the same rules foreseen for income tax.

 

Income tax expenses

 

The following shows a breakdown of the income tax recognized in profit and loss for the years ended December 31:

 

   2015   2014 
Current  income tax   3,510,546    6,389,978 
Deferred  tax   (2,800,193)   (955,123)
Income tax expense   710,353    5,434,855 

 

Reconciliation of the income tax expense

 

The reconciliation between income tax expense and the tax determined based on the legal rate applicable to the company in Colombia is as follows:

 

   2015       2014     
Net income (loss) before income tax   (5,578,626)        11,104,428      
  Standard rates   39%        34%     
 Income tax at nominal rate   (2,175,664)   39%   3,775,506    34%
Adjustments for the calculation of income tax:                    
Exchange difference   1,305,129    (23.4)%   587,897    5.3%
Differences in the tax rates and tax bases   1,069,310    (19.2)%   (151,244)   (1.4)%
Wealth tax   253,422    (4.5)%   -    0.0%
Nondeductible expenses   194,176    (3.5)%   378,218    3.4%
Valuation of investments   48,129    (0.9)%   922,028    8.3%
Nontaxable income   (19,986)   0.4%   (17,352)   (0.2)%
Others   35,837    (0.6)%   (60,198)   (0.5)%
Income tax calculated   710,353    (12.7)%   5,434,855    48.9%
 Current  income tax   3,510,546         6,389,978      
 Deferred  tax   (2,800,193)        (955,123)     
    710,353         5,434,855      

 

F-27 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

The effective rate at December 31, 2015 is -12.7% (2014, 48.9%). The decrease relative to the previous year is mainly due to the following: a) the consolidated loss, b) the existence in 2015 of wealth tax, which is nondeductible, c) differential tax rates regarding to free trade zone companies and d) Exchange difference recorded on companies with functional currency different than Ecopetrol S.A.

 

The income and supplementary tax returns for the tax years 2011-2014 and CREE returns for the tax years 2013 and 2014 are subject to acceptance and review by the tax authorities. The Group Companies' management considers that the amounts recorded as liabilities for taxes payable are sufficient and are supported by current regulations, doctrine and jurisprudence for purposes of addressing any claims that may arise with respect to such years. The Company's strategy involves not making tax decisions by adopting aggressive or risky stances that may bring its tax returns into question.

 

Deferred income tax

 

The balance of deferred taxes is comprised as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Deferred Tax asset   8,239,472    4,245,416    3,893,883 
Current   1,173,786    690,665    928,955 
Non-current   7,065,686    3,554,751    2,964,928 
    8,239,472    4,245,416    3,893,883 
Deferred Tax liability   6,026,050    4,168,144    4,119,815 
Current   127,452    108,294    135,217 
Non-current   5,898,598    4,059,850    3,984,598 
    6,026,050    4,168,144    4,119,815 
Total deferred income tax   2,213,422    77,272    (225,932)

 

Deferred income tax was calculated considering the rates applicable to the maturity date according to the tax regulations applicable to each business group company (see accounting policy in paragraph 4.14).

 

The detail of deferred tax assets and deferred tax liabilities is as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Deferred tax assets               
Property, plant and equipment (1)   3,804,927    803,616    240,598 
Natural and environmental resources (1)   289,323    203,943    70,170 
Borrowings and other financial liabilities   986,689    268,210    96,246 
Accounts payable   726,256    111,300    504,816 
Accrued liabilities and provisions   1,867,461    1,814,433    1,459,483 
Tax losses   238,193    227,078    202,240 
Employee benefits (2)   -    352,720    469,633 
Others   326,623    464,116    850,697 
Total deferred tax assets   8,239,472    4,245,416    3,893,883 

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Deferred tax liabilities               
Goodwill   262,291    473,293    312,151 
Property, plant and equipment (1)   2,607,383    1,830,731    1,093,033 
Natural and environmental resources (1)   1,281,368    1,102,278    1,965,833 
Borrowings and other financial liabilities   1,527,501    571,105    237,883 
Others   347,507    190,737    510,915 
Total deferred tax liabilities   6,026,050    4,168,144    4,119,815 

 

F-28 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

(1)For tax purposes, natural resources and property, plant and equipment have specific useful lives. According to IFRS, the useful life is determined by a technical analysis. This difference will result in a difference in the depreciable basis for accounting and tax purposes.

 

(2)Deferred tax generated by the difference in valuation of the actuarial liability.

 

The movements of deferred income tax for the years ended December 31, 2015 and 2014 is as follows:

 

Deferred tax assets

 

   Property,
plant and
equipment (1)
   Natural and
environmental
resources (1)
   Borrowings
and other
financial
liabilities
   Accounts
payable
   Accrued
liabilities
and
provisions
   Tax
losses
   Employee
benefits (2)
   Others   Total 
January 1, 2014   240,598    70,170    96,246    504,816    1,459,483    202,240    469,633    850,697    3,893,883 
Recognized in deferred income tax expense   563,018    133,773    171,964    (393,516)   354,950    24,838    266,253    (268,411)   852,869 
Recognized in other comprehensive income (a)   -    -    -    -    -    -    (383,166)   (118,170)   (501,336)
December 31, 2014   803,616    203,943    268,210    111,300    1,814,433    227,078    352,720    464,116    4,245,416 
Recognized in deferred income tax expense   3,001,311    85,380    718,479    614,956    53,028    11,115    370,863    (137,493)   4,717,639 
Recognized in other comprehensive income (a)   -    -         -    -    -    (723,583)   -    (723,583)
December 31, 2015   3,804,927    289,323    986,689    726,256    1,867,461    238,193    -    326,623    8,239,472 

 

Deferred tax liabilities

 

   Goodwill   Property, plant
and equipment (1)
   Natural and
environmental
resources (1)
   Borrowings and
other financial
liabilities
   Others   Total 
January 1, 2014   312,151    1,093,033    1,965,833    237,883    510,915    4,119,815 
Recognized in deferred income tax expense   161,142    318,363    (863,555)   333,222    (51,426)   (102,254)
Foreign exchange        419,335              (268,752)   150,583 
Recognized in other comprehensive income (a)                            - 
December 31, 2014   473,293    1,830,731    1,102,278    571,105    190,737    4,168,144 
Recognized in deferred income tax expense   (211,002)   895,735    179,090    788,797    264,826    1,917,446 
Recognized in other comprehensive income (a)   -    -    -    167,599    -    167,599 
Foreign exchange (a)   -    (119,083)   -    -    (108,056)   (227,139)
December 31, 2015   262,291    2,607,383    1,281,368    1,527,501    347,507    6,026,050 

 

(a)The following is the breakdown of income tax recorded against other comprehensive income:

 

For the year ended December 31, 2015

 

   Base   Deferred tax   Total 
Actuarial valuation (1)   (2,128,184)   723,582    (1,404,602)
Derivative financial instruments  (2)   100,134    (40,051)   60,083 
Cash flow hedging for future crude oil exports  (2)   344,836    (127,545)   217,291 
Others (2)   -    108,057    108,057 
    (1,683,214)   664,043    (1,019,171)

 

For the year ended December 31, 2014

 

   Base   Deferred tax   Total 
Actuarial valuation (1)   (1,126,959)   383,166    (743,793)
Others  (2)   -    268,753    268,753 
    (1,126,959)   651,919    (475,040)

 

(1)Corresponds to deferred income tax.
(2)Corresponds to current income tax.

 

F-29 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

Transfer pricing

 

Income taxpayers, who had entered into transactions with related parties abroad, and/or with residents of countries considered as tax havens, are under the obligation of determining, for income tax purposes, their ordinary and extraordinary income, costs and deductions, and assets and liabilities, taking into account the denominated market prices and profit margins for these transactions (Arm’s length principle).

 

The Group companies presented the 2014 statement of Transfer Pricing and its corresponding corroborating documentation. There were no adjustments to income tax as a result of the 2014 transfer price analysis.

 

For the 2015 tax year, transactions with related parties from abroad, as well as the business conditions under which such transactions took place and the overall structure thereof, did not experience significant changes compared to the previous year. As a result, it is possible to infer that such transactions were carried out in accordance with the arm's length principle. It is estimated that no significant adjustments will be required arising from the transfer pricing analysis for 2015, which would otherwise involve changes to the income tax provision for 2015.

 

Wealth tax

 

The wealth tax was established by means of Act 1739 of 2014; its taxable event is the possession of wealth at January 1, 2015, 2016 and 2017, and it is due by income taxpayers. At January 1, 2015, the conditions for determining the wealth tax to be paid in 2015 were as follows:

 

Range of equity  Rate
>COP$ 0 < COP$ 2,000,000  (Taxable base)* 0.20%
>= COP$ 2,000,000 < COP$ 3,000,000  (Taxable base- 2,000,000,000) *0.35%+4,000,000
>= COP$ 3,000,000 < COP$ 5,000,000  (Taxable base - 3,000,000,000) *0.75%+ 7,500,000
>= COP$ 5,000,000  (Taxable base - 5,000,000,000) *1.15% + 22,500,000

Taxable base = Fiscal equity

 

During 2015, the wealth tax incurred by the Ecopetrol Business Group amounted to COP$ 649,800, which was recognized as an expense and was paid in full in this year (note 28).

 

10.Equity instruments measured at fair value

 

The balance of equity instruments measured at fair value is comprised as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Equity instruments               
Empresa de Energia de Bogotá (1)   478,618    1,072,867    968,735 
Interconexión Eléctrica S.A (2)   434,870    508,599    536,298 
    913,488    1,581,466    1,505,033 

 

(1)As part of Decree 2305 of 2014, The Company obtained authorization from the National Government to start the sale of its stock ownership in Empresa de Energía de Bogotá.

 

As a result of the above, at July 27, 2015, the Company sold 352,872,414 shares in at a sales price of COP$ 1,740 per share. The amount of the transaction was COP$ 613,998. In order to continue the sales process, Ecopetrol will carry out up to three additional auctions in order to sale the remaining equity instruments. The gain on sale amounted COP$72,339, of which COP$52,931 recorded against Equity instruments assets and COP$19,405 corresponded to realized gain accumulated in other comprehensive income.

 

At December 31, 2015, stock ownership is 278,225,586 shares equivalent to 3.03% of the total outstanding shares. At December 31, 2014 and January 1, 2014 the participation of the Company amounted to 631,098,000 shares equivalent to 6.87% of the total outstanding shares.

 

F-30 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

(2)In April 13, 2015 as part of Act 226 of 1995, the National Government issued approval to start the divestiture process of the shares that Ecopetrol S.A. owns in Interconexión Eléctrica S.A. E.S.P., taking in the recommendation of Ecopetrol’s Board of Directors. Ecopetrol S.A.’s stock ownership in Interconexión Eléctrica S.A. ESP amounts to a total of 58,925,480 shares (equivalent to a 5.32% of the total outstanding shares).

 

Resources obtained from the sale of these companies will be used to fund the Company’s investment plan.

 

The movement of equity instruments measured at fair value at December 31, 2015 and the year ended December 31, 2014 is as follows:

 

   December 31,   December 31, 
   2015   2014 
Opening balance   1,581,466    1,505,033 
Fair value adjustments   (106,911)   76,433 
Proceeds from sales of shares   (613,998)   - 
Gain on sale of shares   52,931    - 
Closing balance   913,488    1,581,466 

 

These equity instruments are measured at fair value through other comprehensive income. Its hierarchy level is 1, using as reference quoted prices of shares on the Bolsa de Valores de Colombia (Colombian Stock Market).

 

11.Other financial assets

 

The balance of other financial assets is comprised as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Assets measured at fair value through profit and loss               
Securities issued by:               
US Government   895,425    257,697    271,525 
Financial entities   323,939    610,677    711,418 
Colombian Government   228,148    271,252    92,969 
Government-sponsored enterprises   91,303    261,896    204,258 
Private companies or mixed economy   36,844    27,138    62,238 
    1,575,659    1,428,660    1,342,408 
Assets measured at amortized cost               
Securities issued or secured by the Colombian government   3,994    14,080    568,397 
Other financial assets   5,370    39,079    140,828 
    9,364    53,159    709,225 
Hedging instruments   356    -    - 
Total   1,585,379    1,481,819    2,051,633 
Current   329,227    817,977    1,547,133 
Non-current   1,256,152    663,842    504,500 
    1,585,379    1,481,819    2,051,633 

 

The average yield of the Colombian pesos portfolio and U.S dollar portfolio for the year ended December 31, 2015 was 5.5% (2014 -4.2%) and 0.45%, respectively. The fair value measured is recognized against Finance result (See note 30).

 

The table below reflects the credit quality of issuers and counterparties in transactions involving the other financial assets:

 

   2015   2014 
Credit quality of issuers  Local Rating   Global Rating   Total   Local Rating   Global Rating   Total 
F1+   200,016    17,477    217,493    345,810    135,946    481,756 
F1   -    48,919    48,919    -    290,520    290,520 
AAA   132,881    997,335    1,130,216    47,023    527,276    574,299 
AA+   -    -    -    -    2,245    2,245 
BBB   -    125,936    125,936    -    79,602    79,602 
Unrated   62,815    -    62,815    53,397    -    53,397 
Total   395,712    1,189,667    1,585,379    446,230    1,035,589    1,481,819 

 

F-31 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

The credit quality of financial assets policy is describe in Note 31.3 – Credit risk.

 

11.1Restrictions

 

The portfolio of securities includes restricted resources made up of fixed yield investments entered into based on the court rulings linked to the Derecho Comuneros – Santiago de las Atalayas y Pueblo Viejo de Cusiana proceedings, with regard to the attachment and seizure of royalty payments that Ecopetrol had to pay pursuant to Royalty Contracts No. 15, 15A, 16 and 16A, declared null and void in due course by the State Council ruling of September 13, 1999. The breakdown is as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Securities issued by:               
US Government   461,566    148,230    19,175 
Colombian Government   129,261    114,966    71,241 
Government-sponsored enterprises   52,568    137,276    162,129 
Private companies or mixed economy   28,560    22,603    52,957 
Financial entities   27,877    125,338    65,889 
    699,832    548,413    371,391 

 

11.2Maturity

 

The following are the maturities of other financial assets at December 31, 2015:

 

   Non-restricted
securities
   Restricted
securities
   Total 
Up to 1 year   292,155    37,072    329,227 
1 - 2 years   358,844    380,493    739,337 
2 - 5 years   224,798    245,577    470,375 
> 5 years   9,750    36,690    46,440 
    885,547    699,832    1,585,379 

 

11.3Fair value

 

The classification of the other financial assets at fair value at December 31, 2015, December 31, 2014 and January 1, 2014 is comprised as follows:

 

    December 31,   December 31,   January 1, 
Fair value hierarchy   2015   2014   2014 
Level 1    975,262   257,697   149,643
Level 2    600,397   1,170,963   1,192,765
Total    1,575,659   1,428,660   1,342,408

 

There were no transfers between hierarchy levels during the years.

 

The securities comprising Ecopetrol's portfolio are valued on a daily basis pursuant to the provisions issued by the Financial Superintendence of Colombia. To this end, we use the information provided by the entities authorized for this purpose, which collect data from active markets. For cases in which market data is not available, other directly or indirectly observable data is used.

 

For dollar-denominated investments, the information providers are as follows: JP Morgan, Bloomberg, Merrill Lynch and Infovalmer. For investments denominated in pesos, the sole information provider is Infovalmer, an entity authorized by the Financial Superintendence of Colombia for the provision of this service.

 

F-32 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

For the process of establishing levels of the fair value for investments, in addition to the information used for valuation, other relevant aspects are also taken into account, such as the issuer rating, investment rating and issuer risk analysis performed by Ecopetrol, thus making it possible to establish the appropriate hierarchy level for investments.

 

12.Other assets

 

The balance of other assets is comprised as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Current               
Partners in joint operations (Note 33)   431,523    761,703    383,233 
Advanced payments to contractors and suppliers   370,269    323,370    330,803 
Prepaid expenses   226,842    259,360    181,279 
Other advances and agreements   33,022    31,345    20,010 
Related parties (Note 32)   28,668    9,338    15,558 
Total current   1,090,324    1,385,116    930,883 
Non-current               
Prepaid expenses   282,373    290,592    176,829 
Judicial deposits   146,701    86,485    59,827 
Trust funds (1)   125,720    460,335    460,470 
Employee benefits   91,625    153,862    142,077 
Goods in lieu in payment   38,731    38,758    58,477 
Studies and projects   28,894    18,834    10,756 
Assets retirement funds   27,211    22,756    19,403 
Advances and deposits   18,405    16,626    11,660 
Other assets   6,720    2,468    1,557 
Total non-current   766,380    1,090,716    941,056 
Total   1,856,704    2,475,832    1,871,939 

 

(1) The balance at December 31, 2015 mainly includes deposits to the Oil Savings and Stabilization Fund (from the Spanish Fondo de Ahorro y Estabilización Petrolera - FAEP) in Ecopetrol’s favor to address the remainder of the National Royalties Fund. Its sole purpose is the payment of debts and financing development programs and projects in hydrocarbon producing and non-producing municipalities and departments. Ecopetrol will make disbursements as the Ministry of Finance issues the respective approvals.

 

At the close of 2015, the pension resources managed by Fiduciaria Bancolombia (equivalent to COP$342,951, from the termination of the Cravo Norte Partnership agreement with Occidental de Colombia) were returned to Ecopetrol S.A., since the pension obligation arising from such agreement is supported by the pension trusts described in note 22 - Provisions for employee benefits.

 

13.Non-current assets held for sale and associated liabilities

 

During the final quarter of 2015, and as part of the business group's divestment plan, the process began regarding the sale of assets in the La Hocha and La Cañada fields, where Hocol S.A. holds interests. The Group intends to sell these assets over the next 12 months.

 

The detail of assets of these fields is as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Plant and equipment   201,466    1,318    1,318 
Pipelines, networks and lines   34,179    -    - 
Buildings   4,700    41    41 
Other assets   2,400    3    3 
    242,745    1,362    1,362 

 

The breakdown of liabilities associated with assets held for sale amounted to COP$17,628 and mainly correspond to asset retirement obligation and environmental commitments of such assets.

 

F-33 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

The result associated with non-current assets held for sale during 2015 is as follows:

 

   December 31, 
   2015 
Revenue   52,335 
Cost of sale   (97,880)
Gross income   (45,545)
Operational expenses   (120,104)
Finance results, net   10,807 
Loss before income tax   (154,842)
Income tax   (8,017)
Net loss   (162,859)

 

14.Investments in associates and joint ventures

 

14.1Investments in companies information

 

The balance of the investments in associates and joint ventures is as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Investments in joint ventures               
Equion Energía Limited   1,430,206    1,392,895    1,634,602 
Ecodiesel Colombia S.A.   37,161    29,908    25,343 
    1,467,367    1,422,803    1,659,945 
Less- Impairment               
Equion Energía Limited   (172,528)   -    - 
    1,294,839    1,422,803    1,659,945 
Investments in associates               
Offshore International Group   1,097,929    1,017,410    879,621 
Invercolsa S.A.   61,503    56,742    109,664 
Serviport S.A.   8,490    8,445    8,445 
Sociedad Portuaria Olefinas   649    649    649 
    1,168,571    1,083,246    998,379 
Less:  Impairment:               
Offshore International Group   (530,350)   (114,734)   - 
Serviport S.A.   (1,126)   (1,126)   (1,126)
    637,095    967,386    997,253 
    1,931,934    2,390,189    2,657,198 

 

The details of the investments in associates and jointly controlled entities’ ownership, economic activity, address, country of operations and financial information is shown in Exhibit I.

 

The following shows a breakdown of the changes in the investments in companies:

 

For the year ended December 31, 2015

 

   Associates   Joint Ventures   Total 
Opening balance   967,386    1,422,803    2,390,189 
Effects of equity method through               
Profit or loss   (72,794)   26,107    (46,687)
Foreign currency translation   199,301    309,667    508,968 
Dividends declared   (41,182)   (291,210)   (332,392)
Impairment   (415,616)   (172,528)   (588,144)
Closing balance   637,095    1,294,839    1,931,934 

 

F-34 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

For the year ended December 31, 2014

 

   Associates   Joint Ventures   Total 
Opening balance   997,253    1,659,945    2,657,198 
Effects of equity method through:               
Profit or loss   30,485    135,585    166,070 
Foreign currency translation   135,882    212,788    348,670 
Dividends declared   (81,500)   (585,515)   (667,015)
Impairment   (114,734)   -    (114,734)
Closing balance   967,386    1,422,803    2,390,189 

 

14.2Impairment on the value of investments in companies

 

The group's investments in associates and joint ventures are recorded through the equity method. Once the equity method has been applied, Ecopetrol assesses whether there is any objective evidence that the value of its investment in these companies has been impaired, especially in respect of those that were acquired with goodwill, using their value-in-use as a basis, which involves the valuation thereof by discounted free cash flow.

 

The companies in respect of which Ecopetrol assessed the objective existence of evidence of impairment, after application of the equity method, were: Equion Energía Limited and Offshore International Group. The assumptions used to determine the value-in-use of the companies are described in Note 18 - Impairment on the value of assets for companies from the Exploration and Production Segment.

 

As a result, the company recognized impairment in the value of its investments in these companies, as follows (Note 29):

 

Company  2015   2014 
Equion Energia Limited   (172,528)   - 
Offshore International Group   (415,616)   (114,734)
    (588,144)   (114,734)

 

The impairment is due mainly to the current adverse economic context faced by the hydrocarbons sector, which results in a reduction in forecast oil prices and an increase in market and country risk that's reflected in the discount rate.

 

Given the current adverse economic environment faced by the hydrocarbon sector, the investments in companies associates and joint ventures are exposed to certain future risks such as a further decline in oil prices, lower profit margins, changes in cost profiles, changes in levels of capital expenditures and maintenance, a reduction in recoverable reserves amount, and an increase in market and country risk that is reflected in a higher discount rate. Any significant change in the estimates and judgments used to calculate these variables can have a material effect on the recognition or recovery of impairment on the value of investments in companies. 

 

14.3Restrictions over investments in associates

 

The number of shares held by Ecopetrol S.A. in Invercolsa has been the subject of a legal dispute with another shareholder of such company. The courts ruled in favor of Ecopetrol in a court decision in 2011, which established that 324 million shares (equivalent to 11.58% of Invercolsa's share capital) should be returned to Ecopetrol. As a result, the ownership interest in this company is 43.35%. The dividends paid in connection with the shares returned to Ecopetrol are being disputed, as is the ownership of shares representing 8.53% of Invercolsa's share capital. The resolution of these matters is still pending.

 

F-35 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

14.4Additional information about associated companies and joint ventures

 

The balance of assets, liabilities and results of material associates and joint ventures is comprised as follows

 

   December 31, 2015   December 31, 2014   January 1, 2014 
   Equion Energía
Limited
   Offshore
International
Group
   Equion Energía
Limited
   Offshore
International
Group
   Equion Energía
Limited
   Offshore
International
Group
 
Statement of financial position                              
Current assets   854,445    310,677    1,052,893    350,969    1,900,976    386,259 
Non-current assets   2,114,689    2,089,841    1,984,484    1,893,416    1,512,282    1,663,224 
Total assets   2,969,134    2,400,518    3,037,377    2,244,385    3,413,258    2,049,483 
Current liabilities   549,281    477,611    815,463    511,918    793,321    562,447 
 Non-current liabilities   352,182    409,946    217,461    380,543    151,488    410,689 
Total liabilities   901,463    887,557    1,032,924    892,461    944,809    973,136 
Equity   2,067,671    1,512,961    2,004,453    1,351,924    2,468,449    1,076,347 
Other complementary information                              
Cash and cash equivalents   340,797    25,760    470,710    63,858    155,479    47,112 
Financial obligations, short-term   423,132    337,506    690,741    334,944    737,610    307,329 
Financial obligations, long-term   751    33,025    447    35,046    3,817    115,999 

 

   For the years ended at December 31, 
   2015   2014 
   Equion Energía
Limited
   Offshore
International
Group
   Equion Energía
Limited
   Offshore
International
Group
 
Statement of profit or loss                    
Revenue   1,218,796    463,660    1,261,578    199,316 
Costs   (958,467)   (654,095)   (602,751)   (137,654)
Administration and other expenses   (74,258)   (128,895)   (16,323)   (51,937)
Financial income (expenses)   37,970    (8,528)   34,115    (815)
Income tax   (209,221)   90,294    (419,039)   (5,097)
Net income for the period   14,820    (237,564)   257,580    3,813 

 

Below, there is a reconciliation of equity between the most significant participations and the carrying amount of investments:

 

   December 31, 2015   December 31, 2014   January 1, 2014 
   Equion
Energía
Limited
   Offshore
International
Group
   Equion
Energía
Limited
   Offshore
International
 Group
   Equion
Energía
Limited
   Offshore
International
 Group
 
Equity of the associate   2,067,671    1,512,961    2,004,453    1,351,924    2,468,449    1,076,347 
Adjustment to unrealized loss   -    -    (9,940)   -    -    - 
Adjusted equity   2,067,671    1,512,961    1,994,513    1,351,924    2,468,449    1,076,347 
% of Ecopetrol’s ownership   51%   50%   51%   50%   51%   50%
Ecopetrol’s ownership   1,054,513    756,482    1,017,202    675,962    1,258,909    538,173 
(Plus) Goodwill   375,693    226,713    375,693    341,448    375,693    341,448 
(Less) Impairment   (172,528)   (415,616)   -    (114,734)   -    - 
Equity of the associate   1,257,678    567,579    1,392,895    902,676    1,634,602    879,621 

 

F-36 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

15.Property, plant and equipment

 

The following shows a breakdown of the changes in property, plant and equipment and its depreciation and impairment for the years ended December 31, 2015 and 2014:

 

   Plant and
equipment
   Pipelines,
networks and
lines
   Work in progress
(1)
   Buildings   Lands   Other   Total 
Cost                                   
Balance at December 31, 2014   16,109,035    19,938,115    24,009,694    5,199,417    3,614,237    3,135,873    72,006,371 
Additions   2,720,120    2,213,663    2,446,904    755,565    112,972    299,709    8,548,933 
Asset retirement cost additions   242,815    (115,608)   14,184    -    -    -    141,391 
Interest capitalized   -    -    553,061    -    -    -    553,061 
Effect of exchange rate differences  capitalized on borrowings   -    -    110,485    -    -    -    110,485 
Disposals of assets   (94,227)   (187,964)   (32,842)   (5,060)   (9,786)   (70,445)   (400,324)
Foreign currency translation   5,093,932    2,526,312    159,154    258,070    354,898    190,381    8,582,747 
Other (reclassifications)   13,288,547    2,481,567    (16,245,630)   271,364    (3,370)   98,280    (109,242)
Balance at December 31, 2015   37,360,222    26,856,085    11,015,010    6,479,356    4,068,951    3,653,798    89,433,422 
                                    

Accumulated depreciation and Impairment

                                   
Balance at December 31, 2014   (7,446,991)   (6,071,305)   (1,209,229)   (1,146,453)   (70,332)   (397,054)   (16,341,364)
Depreciation expense   (1,168,864)   (1,300,687)   -    (329,396)   -    (124,309)   (2,923,256)
Impairment losses recognized in profit or loss (Note 18)   (2,787,539)   (584,736)   (509,195)   (161,431)   (13,689)   (88,164)   (4,144,754)
Disposals of assets   75,305    90,389    -    4,208    -    64,283    234,185 
Foreign currency Translation   (219,358)   (481,180)   (404,872)   (37,259)   -    (10,491)   (1,153,160)
Other (reclassifications)   (1,922,302)   (224,854)   2,103,730    (28,460)   70,332    1,554    - 
Balance at December 31, 2015   (13,469,749)   (8,572,373)   (19,566)   (1,698,791)   (13,689)   (554,181)   (24,328,349)
Net balance at December 31, 2015   23,890,473    18,283,712    10,995,444    4,780,565    4,055,262    3,099,617    65,105,073 

 

(1)In October 2015, the Refineria de Cartagena project came online. Part of the investment in this project, which had been accumulated under Construction in progress (COP$13,853,231), was reclassified to different asset classes, to begin depreciation thereof.

 

The balance for projects in progress at December 31, 2015, mainly includes investments for development projects in the Castilla, Rubiales and Chichimene fields, as well as projects to modernize Refineria de Barrancabermeja and the industrial services master plan.

 

   Plant and
equipment
   Pipelines,
networks and 
lines
   Work in progress (1)   Buildings   Lands   Other   Total 
Cost                                   
Balance at  January 1, 2014   14,458,014    16,516,463    17,427,438    3,894,171    3,438,685    2,784,635    58,519,406 
Additions   1,257,314    1,783,076    4,225,263    911,098    129,121    617,696    8,923,568 
Interest capitalized   -    -    432,307    -    -    25,558    457,865 
Effect of exchange rate differences capitalized on borrowings   -    -    52,755    -    -    -    52,755 
Disposals of assets   (187,009)   (70,256)   (30,907)   (18,425)   (24,001)   (228,852)   (559,450)
Foreign currency Translation   583,293    788,499    2,867,952    87,352    218,064    67,067    4,612,227 
Other (reclassifications)   (2,577)   920,333    (965,114)   325,221    (147,632)   (130,231)   - 
Balance at December 31, 2014   16,109,035    19,938,115    24,009,694    5,199,417    3,614,237    3,135,873    72,006,371 
                                    

Accumulated depreciation and Impairment

                                   
Balance at  January 1, 2014   (6,241,195)   (4,585,338)   -    (758,753)   -    (334,703)   (11,919,989)
Depreciation expense   (1,027,774)   (1,191,217)   -    (368,919)   -    (111,700)   (2,699,610)
Impairment losses recognized in profit
or loss (Note 18)
   (78,946)   (85,483)   (1,209,229)   (11,684)   (70,332)   (36,135)   (1,491,809)
Disposals of assets   160,868    28,193    -    4,047    -    66,627    259,735 
Foreign currency translation   (262,762)   (196,566)   -    (21,007)   -    (9,356)   (489,691)
Other (reclassifications)   2,818    (40,894)   -    9,863    -    28,213    - 
Balance at December 31, 2014   (7,446,991)   (6,071,305)   (1,209,229)   (1,146,453)   (70,332)   (397,054)   (16,341,364)
Net balance at December 31, 2014   8,662,044    13,866,810    22,800,465    4,052,964    3,543,905    2,738,819    55,665,007 

 

(1)Mainly includes investments in the modernization of the Refinería de Cartagena plant in the amount of COP$16,888,232 (January 1, 2014 - COP$10,322,246) and projects from the drilling plan in Ecopetrol in the amount of COP$5,736,860 (January 1, 2014 - COP$4,943,214).

 

F-37 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

 

16.Natural and environmental resources

 

The following shows a breakdown of the changes in Natural and environmental resources and its depletion and impairment for the years ended December 31, 2015 and 2014:

 

   Oil and Gas investments   Asset Retirement
Obligation
   Exploration and
Evaluation (1)
   Total 
Cost                    
Balance at December 31, 2014   37,168,922    1,895,149    6,114,019    45,178,090 
Additions   5,776,253    9,520    1,070,988    6,856,761 
Asset retirement cost additions   -    (139,670)   -    (139,670)
Disposals   (13,475)   -    (56,962)   (70,437)
Dry wells (2)   -    -    (1,266,440)   (1,266,440)
Interest capitalized   -    -    191,365    191,365 
Effect of exchange rate differences capitalized on borrowings   -    -    39,416    39,416 
Foreign currency translation   1,031,595    6,299    272,890    1,310,784 
Other (reclassifications)   185,058    (8,924)   (176,134)   - 
Balance at December 31, 2015   44,148,353    1,762,374    6,189,142    52,099,869 
Accumulated depletion and Impairment                    
Balance at December 31, 2014   (20,223,671)   (833,755)   -    (21,057,426)
Depletion expense   (3,424,212)   (300,650)   -    (3,724,862)
Impairment losses recognized in profit or loss   (2,865,077)   -    -    (2,865,077)
Disposals of assets   9,040    -    -    9,040 
Foreign currency translation   (356,815)   (61,432)   -    (418,247)
Other (reclassifications)   (14,039)   14,039    -    - 
Balance at December 31, 2015   (26,874,774)   (1,181,798)   -    (28,056,572)
Net balance at December 31, 2015   17,273,579    580,576    6,189,142    24,043,297 

 

(1)The balance for Exploration and evaluation primarily includes investments in production projects (direct operation) in Castilla, Chichimene, Apiay, Tibu and Piedemonte. It also includes exploration projects: Kronos, unconventional hydrocarbons and Tayrona

 

(2)It mainly includes dry wells in Ecopetrol S.A. operations for COP$ 912,695, Ecopetrol America Inc. for COP$131,447, Hocol S.A. for COP$139,362 and Ecopetrol Germany for COP$82,936.

 

   Oil and Gas investments   Asset Retirement
Obligation
   Exploration and
Evaluation
   Total 
Cost                    
Balance at January 1, 2014   31,277,932    1,227,664    5,575,489    38,081,085 
Additions (1)   4,687,423    -    1,914,257    6,601,680 
Asset retirement cost additions   -    647,441    -    647,441 
Disposals   (11)   -    (120,506)   (120,517)
Dry wells (2)   -    -    (1,563,384)   (1,563,384)
Interest capitalized   -    -    182,833    182,833 
Effect of exchange rate differences capitalized on borrowings   -    -    33,416    33,416 
Foreign currency translation   944,723    20,044    350,769    1,315,536 
Other (reclassifications)   258,855    -    (258,855)   - 
Balance at December 31, 2014   37,168,922    1,895,149    6,114,019    45,178,090 
Accumulated depletion and Impairment                    
Balance at January 1, 2014   (15,707,554)   (648,052)   -    (16,355,606)
Depletion expense   (3,466,284)   (160,106)   -    (3,626,390)
Impairment losses recognized in profit or loss   (694,720)   -    -    (694,720)
Disposals of assets   11    -    -    11 
Foreign currency translation   (368,513)   (12,208)   -    (380,721)
Other (reclassifications)   13,389    (13,389)   -    - 
Balance at December 31, 2014   (20,223,671)   (833,755)   -    (21,057,426)
Net balance at December 31, 2014   16,945,251    1,061,394    6,114,019    24,120,664 

 

(1)Additions are mainly represented in the following fields: Castilla, Casabe, Chichimene, Rubiales, Pauto, Caño Sur Este, Quifa, Cusiana, Nare y Akacías.

 

F-38 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

(2)It mainly includes dry wells in Ecopetrol S.A. operations for COP$527,670, Ecopetrol America Inc. for COP$462,060, Ecopetrol Brazil for COP$116,608, Ecopetrol Germany for COP$ 285,548 and Hocol S.A. for COP$171,467.

 

The depletion method used is the units-of-production method.

 

Accounting For Suspended Exploratory Wells

 

The following table represents a classification by ages for constructions in progress based on the drilling completion date and the number of projects that are in ongoing drilling for a period exceeding one year as from the completion date.

 

   2015   2014 
Between 1 and 3 years (a)   490,184    416,687 
Between 3 and 5 years (b)   100,316    25,703 
More than 5 years (c)   161,392    41,622 
Total suspended exploratory Wells   751,892    484,011 
No. of projects exceeding 1 year   59    42 
Wells under 1 year of suspended   280,801    259,932 

 

(a)Corresponds to 25 Ecopetrol’s exploratory wells, 3 wells of Ecopetrol America Inc. and 3 of Offshore International Group.

 

(b)Corresponds to 13 Ecopetrol’s exploratory wells two of them stratigraphic, 3 wells of Ecopetrol America Inc. and 3 of Offshore International Group.

 

(c)Corresponds to 9 Ecopetrol’s exploratory wells six of them stratigraphic, 1 well of Ecopetrol America Inc. and 7 of Offshore International Group.

 

17.Intangibles

 

The following shows a breakdown of the changes in Intangibles and their amortization for the years ended December 31, 2015 and 2014:

 

   Licenses and
software
   Other
intangibles (1)
   Total 
Cost               
Balance at December 31, 2014   575,535    127,519    703,054 
Additions   107,815    4,440    112,255 
Disposals   (615)   -    (615)
Foreign currency translation   53,242    -    53,242 
Reclassifications   (2,862)   112,104    109,242 
Balance at December 31, 2015   733,115    244,063    977,178 
Accumulated amortization               
Balance at December 31, 2014   (425,357)   (32,545)   (457,902)
Amortization expense   (66,043)   (24,196)   (90,239)
Disposals   309    23    332 
Foreign currency translation   (41,318)   -    (41,318)
Reclassifications   (1,375)   1,375    - 
Balance at December 31, 2015   (533,784)   (55,343)   (589,127)
Net balance at December 31, 2015   199,331    188,720    388,051 
Useful life   <5years    <7years      

 

F-39 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

   Licenses and
software
   Other
intangibles (1)
   Total 
Cost               
Balance at January 1, 2014   534,789    504,946    1,039,735 
Additions   29,082    82,936    112,018 
Disposals   (24,774)   (367,910)   (392,684)
Foreign currency translation   32,552    -    32,552 
Reclassifications   3,886    (92,453)   (88,567)
Balance at December 31, 2014   575,535    127,519    703,054 
Accumulated amortization               
Balance at January 1, 2014   (363,912)   (403,753)   (767,665)
Amortization expense   (59,828)   (16,409)   (76,237)
Impairment losses recognized in profit or loss   (3,304)   -    (3,304)
Disposals   23,745    367,910    391,655 
Foreign currency translation   (2,351)   -    (2,351)
Reclassifications   (19,707)   19,707    - 
Balance at December 31, 2014   (425,357)   (32,545)   (457,902)
Net balance at December 31, 2015   150,178    94,974    245,152 
Useful life   <5years    <7years      

 

(1)It includes mainly easements and rights to use the pipeline Caño Limón - Coveñas.

 

18.Impairment of Property, plant and equipment, Natural resources and Intangibles

 

As mentioned in section 4.12, each year the Company assesses whether there is evidence of impairment regarding its assets or cash generating units. This is taking into account the first-time application of International Accounting Standards (IFRS), which unlike US GAAP, require the discounting of future cash flows generated by the asset.

 

Given the current adverse economic environment faced by the hydrocarbon sector, the Company is exposed to certain future risks such as a further decline in oil prices, lower refining margins, lower profit margins, changes in cost profiles, changes in levels of capital expenditures and maintenance, a reduction in recoverable reserves amount, and an increase in market and country risk that is reflected in a higher discount rate. Any significant change in the estimates and judgments used to calculate these variables can have a material effect on the recognition or recovery of impairment charges. Different variables have different impact on segments.  For example, the Exploration and Production segment is highly sensitive to the price of hydrocarbons, while the Refining segment is highly sensitive to the discount rate and refining margins given the leverage in that segment.  

 

At December 31, 2015 and 2014, based on impairment tests performed by the Company, the carrying value of certain assets exceeds their recoverable value, which led to recognizing impairment in the income statement of COP$7,009,831 (2014, COP$2,189,833) (Note 29). Information on impairment is detailed by segment below:

 

Impairment  2015   2014 
Exploration and Production   3,649,451    853,179 
Refining and Petrochemicals   3,278,993    1,336,158 
Transportation and Logistics   81,387    496 
    7,009,831    2,189,833 
Recognized in:          
Property, plant and equipment  (Note 15)   4,144,754    1,491,809 
Natural and environmental resources (Note 16)   2,865,077    694,720 
Intangibles (Note 17)   -    3,304 
    7,009,831    2,189,833 

 

F-40 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

18.1Exploration and Production segment

 

The impairment presented during 2015 in the Exploration and Production segment was COP$3,649,451 (2014 – COP$853,179), is as follows:

 

UGE´s with impairment

2015

  Carrying amount  

Recoverable

amount

  

Impairment

loss

 
Operated fields in Colombia   10,323,500    7,645,665    2,430,923 
Fields operated abroad   1,242,979    24,451    1,218,528 
    11,566,479    7,670,116    3,649,451 

 

UGE´s with impairment

2014

  Carrying amount  

Recoverable

amount

  

Impairment

loss

 
Operated fields in Colombia   41,186,400    5,581,870    841,937 
Fields operated abroad   477,484    466,242    11,242 
    4,663,884    6,048,112    853,179 

 

The impairment in this segment is due mainly to the current adverse economic context faced by the hydrocarbons sector, which results in a reduction in forecast oil prices and an increase in market and country risk that's reflected in the discount rate, as well as a reduction in the recoverable reserves amount. The most significant cash generation units impacted by the above factors were the oilfields operated at the national level: Chichimene, Tibú, CP09, Apiay, Llanito and La Hocha, as well as the fields located in the Gulf of Mexico: K2 and Dalmatian.

 

The recoverable amount was calculated based on value-in-use, which relates to the discounted future cash flows for projected hydrocarbon reserves during the economic limit of the production fields. The assumptions used in the model to determine the recoverable values include:

 

-Discount rate of 8.4% (2014, 8.0%), determined as the weighted average cost of capital (WACC) for the Exploration and Production segment.

 

-Oil price - Brent, starting at COP$40/barrel in 2016, and reaching USD 60 in the medium and long term. Prices are based on the compilation of forecasts prepared by independent industry analysts (Wood Mackenzie, Bloomeberg, PIRA, among others), published indexes, and analyses by management.

 

-Balance of crude oil and gas reserves (see note 36)

 

The aggregation of assets for identifying the CGUs is consistent with the previous period.

 

18.2Refining and Petrochemicals segment

 

The impairment presented during 2015 in the Refining and Petrochemicals segment was COP$ 3,278,993 (2014 - 1,336,158), is as follows:

 

UGE´s with impairment

2015

  Carrying amount  

Recoverable

amount

   Impairment loss 
Refineria de Cartagena   26,561,335    23,335,096    3,226,240 
Others   642,139    589,386    52,753 
    27,203,474    23,924,482    3,278,993 

 

UGE´s with impairment

2014

  Carrying amount  

Recoverable

amount

   Impairment loss 
Refinería de Cartagena   18,794,568    17,469,140    1,325,428 
Others   100,311    89,581    10,730 
    18,894,879    17,558,721    1,336,158 

 

F-41 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

The impairment for Refineria de Cartagena is due mainly to the current adverse economic environment faced by the hydrocarbons sector, which results in a reduction in expected refining margins for the coming years, and an increase in market and country risk that's reflected in the discount rate. Additionally, there were higher levels of investment for the commissioning of the Refinery in the final quarter of 2015.

 

The recoverable amount was calculated based on value-in-use, which relates to discounted future cash flows. The assumptions used in the model to determine the recoverable value include an average utilization factor for the Refinery of 94% in the short term and 92% in the long term, a discount rate of 7.2% (2014, 7.1%) and refining margins calculated based on a price study carried out for Reficar.

 

The recoverable amount of Refinería de Cartagena is highly sensitive to changes in future refining margins and the discount rate. Therefore, variations on an individual or grouped basis of these two factors could result in a material adjustment to the impairment recognized.

 

18.3Transportation and Logistics segment

 

The impairment for the transportation and logistics segment in 2015 was COP$81,387 (2014 - COP$496), which relates mainly to the update to the country's hydrocarbon production curves, based on the new price environment and pipeline transportation rates. The discount rate used was 5.9%. (2014, 7.2%).

 

19.Goodwill

 

The balance of Goodwill through the acquisition of controlled companies is comprised as follows

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Transportation and Logistics               
Oleoducto Central SA.   683,496    683,496    683,496 
Exploration and Production               
Hocol Petroleum Limited   537,598    537,598    537,598 
Refining and Petrochemicals               
Andean Chemical Limited   127,812    127,812    127,812 
Propilco S.A.   108,137    108,137    108,137 
    1,457,043    1,457,043    1,457,043 
Less: Impairment losses               
Hocol Petroleum Limited (Note 29)   (297,121)   (30,221)   (30,221)
Total   1,159,922    1,426,822    1,426,822 

 

Given the current adverse economic environment faced by the hydrocarbon sector, the Company is exposed to certain future risks such as a further decline in oil prices, lower refining margins, lower profit margins, changes in cost profiles, changes in levels of capital expenditures and maintenance, a reduction in recoverable reserves amount, and an increase in market and country risk that is reflected in a higher discount rate. Any significant change in the estimates and judgments used to calculate these variables can have a material effect on the recognition of goodwill impairment charges. Different variables have different impact on segments.  For example, the Exploration and Production segment is highly sensitive to the price of hydrocarbons, while the Refining segment is highly sensitive to the discount rate given the leverage in that segment. 

 

At December 31, 2015, the Company assessed the recoverability of the carrying value relating to the goodwill generated in the acquisition of controlled companies, using their value-in-use as a basis, which implies valuation by free cash flow.

 

The main assumptions used for determining the value-in-use of these controlled companies acquired with goodwill, include:

 

-The financial projections for companies in the Exploration and Production Segment were performed through to the economic limit of the fields, or cut to the reversion of the partnership agreements, E&P agreements or others that the companies have entered into, whichever comes first. In the case of companies from the Transportation Segment, the projected time horizon relates to the period in which the concession ends, and for companies from the Refining segment a term of 10 years was used, considering a terminal value.

 

F-42 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

-The company based its projections for revenue from the production segment based on a Brent price starting at USD 40/barrel in 2016, and reaching USD 60 in the medium and long term. Production profiles were estimated based on the views of third parties, which drew on the views of the companies. Projections for revenues and costs for the refining and petrochemicals segment were based on the views of management, as well as reports from third parties. Projections of future cash flows for Ocensa S.A. were created based on the transport rates approved by the resolution from the Ministry of Mines and Energy and production curves updated to reflect the new price environment, as well as existing contracts.

 

-The rates used to discount cash flows reflect the specific risk for each business, as follows: Hocol - 8.4% (2014 – 8.3%). Andean y Propilco - 6.5% (2014 – 6.9%) Oleoducto Central - 4.9% (2014 – 4.5%).

 

As a result, the company recognized an additional goodwill impairment of COP$266,900 in Hocol Petroleum Limited in 2015, brought about mainly by the current adverse economic context faced by the hydrocarbon sector. Regarding companies from the Transportation and Logistics Segment, and the Refining and Petrochemicals Segment, Ecopetrol did not identify the need to recognize goodwill impairment.

 

At December 31, 2014, the Company assessed the recoverability of the carrying value of goodwill and there was no necessary to recognized impairment in this year.

 

20.Loans and borrowings

 

20.1Composition of loans and borrowings

 

  

 

Weighted
average effective
interest rate at
December 31,
2015 -2014

 

December 31,

2015

  

December 31,

2014

   January 1,
2014
 
Local-currency               
Bonds  9.8% - 8.9%  1,960,695    1,931,140    1,927,467 
Syndicated loans  7.7% - 7.9%  4,226,454    4,446,529    4,597,181 
Commercial loans and other  7.9% - 8.2%  945,331    820,700    906,804 
Total local-currency      7,132,480    7,198,369    7,431,452 
                   
Foreign currency                  
Bonds  6.1% - 6.1%  29,121,535    18,527,409    7,821,818 
Commercial loan –  Modernization plan at the Cartagena Refinery  4.1%  - 4.1%  9,107,938    7,480,719    5,831,549 
Other commercial loans  2.1% - 2.0%  7,101,195    1,125,480    835,935 
Other  1.4% - 1.2%  760,190    709,651    772,509 
Total foreign-currency      46,090,858    27,843,259    15,261,811 
Total financial obligations      53,223,338    35,041,628    22,693,263 
Less – short-term      4,573,620    3,517,522    3,121,068 
Total long-term      48,649,718    31,524,106    19,572,195 

 

20.2New borrowings

 

The main financing operations during 2015 and 2014 were as follows:

 

a.Bonds

 

-At June 2015, Ecopetrol S.A. issued USD 1,500 million of bonds in the international market with the following characteristics:

 

Period: 11 years
Maturity date: June 26, 2026
Price: 99.328
Return rate: 5.457%
USA Bond yield: 305 points
Interest rate: 5.375%
Interest pay date: June 26 and December 26

 

F-43 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

-In May and September 2014, Ecopetrol S.A. issued bonds for an amount of USD 2,000 million and USD 1,200 million, respectively. The first-issuance maturity date is May 2045 and its coupon rate is of 5.875%. The second-issuance maturity date is January 2025 and its coupon rate is of 4.125%.

 

-In May, 2014, Oleoducto Central S.A. issued international bonds (Reg/144A) for the amount of USD500 million with a 4% coupon rate, maturing in May 2021.

 

b.Other commercial loans

 

In February 2015, Ecopetrol S.A. entered into a commercial loan of USD 1,925 million. The operation was conducted with the participation 8 international banks. The loan maturity date is in February 2020, payable at maturity and semiannual interest payments of Libor + 140 basis points.

 

c.Other

 

Ecopetrol carried out short-term remittances financed in dollars with domestic banks for the payment of imports in the amount of USD 222 (2014, USD 196), with a financing rate of Libor plus 65 basis points.

 

The following table details the main characteristics of the most significant Group’s loans:

 

Type   Company   Starting
date
  Initial amount at
original currency
(millions)
    Balance at
December 31,
2015
      Balance at
December 31,
2014
    Maturity   Interest
Rate
  Principal
payment
 

 

 

Interest

payment

 Bonds in   Ecopetrol   Dec/2010   COP$ 97,000       -     COP$ 97,000     Dec/2015   Floating   Bullet*   Semi-anuall
 local-currency    S.A.   Dec/2010   COP$ 138,700     COP$ 138,700     COP$ 138,700     Dec/2017   Floating   Bullet   Semi-annually
        Dec/2010   COP$ 479,900     COP$ 479,900     COP$ 479,900     Dec/2020   Floating   Bullet   Semi-annually
        Dec/2010   COP$ 284,300     COP$ 284,300     COP$ 284,300     Dec/2040   Floating   Bullet   Semi-annually
        Dec/2010   COP$ 120,950     COP$ 120,950     COP$ 120,950     Aug/2018   Floating   Bullet   Semi-annually
        Aug/2013   COP$ 168,600     COP$ 168,600     COP$ 168,600     Aug/2023   Floating   Bullet   Semi-annually
        Aug/2013   COP$ 347,500     COP$ 347,500     COP$ 347,500     Aug/2028   Floating   Bullet   Semi-annually
        Aug/2013   COP$ 262,950     COP$ 262,950     COP$ 262,950     Aug/2043   Floating   Bullet   Semi-annually
Syndicated   Ecopetrol S.A.   May/2013   COP$ 1,839,000     COP$ 1,839,000     COP$ 1,839,000     May/2025   Floating   Semi-annually   Semi-annually
 loan in   Oleoducto Bicentenario   Jul/2012   COP$ 2,100,000     COP$ 1,717,625     COP$ 1,717,625     July/2024   Floating   Quarterly   Quarterly
 local-currency   ODL Finance S.A.   Ago/2013   COP$ 647,029     COP$ 608,000     COP$ 608,000     Aug/2020   Floating   Quarterly   Quarterly
Bonds in foreign   Ecopetrol S.A.   Jul/2009   USD $ 1,500     USD $ 1,500 **   USD $ 1,500 **   Jul/2019   Fixed   Bullet   Semi-annually
 currency       Sep/2013   USD $ 350     USD $ 350 **   USD $ 350 **   Sep/2018   Fixed   Bullet   Semi-annually
        Sep/2013   USD $ 1,300     USD $ 1,300 **   USD $ 1,300 **   Sep/2023   Fixed   Bullet   Semi-annually
        Sep/2013   USD $ 850     USD $ 850     USD $ 850     Sep/2043   Fixed   Bullet   Semi-annually
        May/2014   USD $ 2,000     USD $ 2,000     USD $ 2,000     May/2045   Fixed   Bullet   Semi-annually
        Sep/2014   USD $ 1,200     USD $ 1,200     USD $ 1,200     May/2025   Fixed   Bullet   Semi-annually
        Jun/2015   USD $ 1,500     USD $ 1,500       -     June/2026   Fixed   Bullet   Semi-annually
    Oleoducto Central S.A.   May/2014   USD $ 500     USD $ 500     USD $ 500     May/2021   Fixed   Bullet   Semi-annually
International   Refineria de   Dec/2011   USD $ 2,747     USD $ 2,394     USD $ 2,627     Dec/2027   Fixed   Semi-annually   Semi-annually
 commercial    Cartagena   Dec/2011   USD $ 310     USD $ 270     USD $ 297     Dec/2027   Floating   Semi-annually   Semi-annually
 loans    S.A.   Dec/2011   USD $ 440     USD $ 402     USD $ 428     Dec/2025   Floating   Semi-annually   Semi-annually
    Ecopetrol S.A.   Feb/2015   USD $ 1,925     USD $ 1,925 **     -     Feb/2020   Floating   Bullet   Semi-annually
        Mar/2013   USD $ 245     USD $ 196 **   USD $ 196 **   July/2023   Floating   Semi-annually   Semi-annually
        Mar/2013   USD $ 151     USD $ 105 **   USD $ 105 **   July/2019   Floating   Semi-annually   Semi-annually

  

*Bullet - Face value is fully paid on the maturity date.
**Loans designated as hedging instrument (see note 31)

 

20.3Maturity of loans and borrowings

 

The following is the maturity profile, under amortized cost of loans, as of December 31, 2015:

 

   Up to 1 year   1 - 5 years   5-10 years   > 10 years   Total 
Local currency                    
Bonds   186,026    1,079,088    347,752    347,829    1,960,695 
Syndicated credit   591,870    2,195,275    1,439,309    -    4,226,454 
Commercial loans and others   170,034    229,465    323,031    222,801    945,331 
Total local currency   947,930    3,503,828    2,110,092    570,630    7,132,480 
                          
Foreign currency                         
Bonds   1,639,597    9,919,064    10,019,228    7,543,646    29,121,535 
Credit of Cartagena Refinery   901,813    3,324,039    4,345,978    536,108    9,107,938 
Commercial loans   428,475    6,475,621    197,099    -    7,101,195 
Other   655,805    104,385    -    -    760,190 
Total foreign currency   3,625,690    19,823,109    14,562,305    8,079,754    46,090,858 
Total   4,573,620    23,326,937    16,672,397    8,650,384    53,223,338 

 

F-44 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

20.4Breakdown by type of interest rate

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Local-currency               
Fixed interest rate   19,410    940    3,571 
Floating interest rate   7,113,070    7,197,429    7,427,881 
    7,132,480    7,198,369    7,431,452 
Foreign-currency               
Fixed interest rate   36,994,095    25,311,898    12,895,126 
Floating interest rate   9,096,763    2,531,361    2,366,685 
    46,090,858    27,843,259    15,261,811 
Total loans and borrowings   53,223,338    35,041,628    22,693,263 

 

Local currency loans and borrowings at floating rates are mainly indexed to the CPI (Consumer Price Index) and DTF (Fixed Term Deposit). The foreign currency loans and borrowings at floating rates are indexed mainly to the Libor plus a spread.

 

20.5Loan designated as hedging instruments

 

At October 1, 2015, the Board of directors designated foreign currency debt of Ecopetrol S.A as a hedge of expected highly probable U.S. dollar nominated export revenue (see Note 31 - Risk Management) for details.

 

20.6Guarantees and Covenants

 

Financing obtained by Ecopetrol S.A. through capital markets, which correspond to issuance of local and foreign bonds, are not guaranteed.

 

Refineria de Cartagena (Reficar) entered into an international commercial loan for USD 3,497 million to finance the expansion project of the refinery in Cartagena in 2011. This operation imposes restrictions on the Reficar’s debt ratio, except for certain conditions expressly set out in contracts about working capital needs. Regarding financial covenants, Reficar is required to maintain a coverage ratio of minimum debt service of 1.35: 1 at certain times of the loan’s life.

 

Under the same transaction, Reficar entered into a commercial trust and Security and Depositary Agreement to receive the resources of the new refinery to meet specific purposes such as operating expenses, interest and others.

 

For the case of the financing obtained by Oleoducto Bicentenario S.A.S. for the construction of the project and startup of the pipeline, the creation of a main fund was established to manage the funds for the payment of the syndicated loan.

 

20.7Fair value of loans

 

The following shows the loan’s fair value:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Fair value   49,668,119    33,564,765    21,755,619 

 

The Business Group’s financial obligations are recognized in the Financial Statements at their amortized cost, which correspond to the present value of cash flows, discounted at the effective interest rate.

 

F-45 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

For the measurement at fair value, bonds and securities in local currency were valued using Infovalmer reference prices, while for the bonds in US dollars the source taken was Bloomberg. Regarding the other financial obligations for which there is no market benchmark, a present value discounting technique was used. Some of the rates used were those established in the credits as they are considered aligned with the market. These rates add market risk through certain benchmarks (Libor, DTF) and the credit risk (spread) of the Company.

 

21.Trade and other payables

 

The balance of trade and other payables is comprised as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Suppliers   4,979,932    6,229,428    6,391,644 
Dividends payable   693,878    3,704    1,313,596 
Partners’ advances   675,527    1,440,947    849,933 
Deposits received from third parties   571,577    312,787    613,812 
Withholding tax   346,578    385,903    400,982 
Related parties   87,463    107,820    127,093 
Various creditors   402,328    348,815    306,945 
    7,757,283    8,829,404    10,004,005 
Current   7,757,277    8,798,965    9,966,622 
Non-current   6    30,439    37,383 
Total   7,757,283    8,829,404    10,004,005 

 

Carrying amount of trade and other payables approximates their fair value due to the short-term nature.

 

22.Provision for employees benefits

 

The balance of provisions for employees benefits are comprised as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Post-employment benefits               
Healthcare   3,593,428    4,787,793    5,127,275 
Education   535,356    679,890    512,800 
Pension   (262,182)   154,383    730,865 
Bonds   (483,876)   (252,994)   13,183 
Other   41,263    48,126    34,537 
    3,423,989    5,417,198    6,418,660 
Welfare benefits and salaries payable   353,285    308,512    266,420 
Other post-employment benefits   74,841    73,983    66,544 
Total   3,852,115    5,799,693    6,751,624 
Current   1,392,266    1,379,706    1,337,616 
Non-current   2,459,849    4,419,987    5,414,008 
    3,852,115    5,799,693    6,751,624 

 

F-46 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

 

22.1Post-employment benefits liability (asset)

 

The following shows a breakdown of the changes in assets and liabilities of post-employment benefits:

 

   Pension and pension bonds (1)   Healthcare, Education and Others   Total 
   December 31,   December 31,   December 31,   December 31,   December 31,   December 31, 
   2015   2014   2015   2014   2015   2014 
Employee benefits liability                              
 Opening liabilities balance    11,559,018    12,193,924    5,515,809    5,674,612    17,074,827    17,868,536 
 Current service cost   -    -    53,095    64,020    53,095    64,020 
 Past service cost   -    -    -    (87,811)   -    (87,811)
 Interest expense   839,716    821,783    395,977    385,400    1,235,693    1,207,183 
 Actuarial losses   (1,252,017)   (771,717)   (1,490,315)   (232,315)   (2,742,332)   (1,004,032)
 Paid benefits   (711,171)   (684,972)   (304,519)   (288,097)   (1,015,690)   (973,069)
Closing liabilities balance   10,435,546    11,559,018    4,170,047    5,515,809    14,605,593    17,074,827 
                               
Plan assets                              
Opening plan assets balance   11,657,629    11,449,876    -    -    11,657,629    11,449,876 
Return on assets   849,556    773,292    -    -    849,556    773,292 
Change in the effect of the asset ceiling   (329,825)   (50,059)   -         (329,825)   (50,059)
Benefits paid   (711,432)   (688,466)   -    -    (711,432)   (688,466)
Actuarial gains (losses)   (284,324)   172,986    -    -    (284,324)   172,986 
Closing plan assets balance   11,181,604    11,657,629    -    -    11,181,604    11,657,629 
Net post-employment benefits liability (asset)   (746,058)   (98,611)   4,170,047    5,515,809    3,423,989    5,417,198 

 

(1)There is no service cost for pension and pension plans because the beneficiaries were all retired from July 31, 2010.

 

The following shows a breakdown of the changes in profit and loss and other comprehensive income for the years ended December 31, 2015 and 2014:

 

   2015   2014 
Recognized in profit and loss        
Service cost   53,095    (23,791)
Interest cost, net   386,137    433,891 
    439,232    410,100 
           
 Recognized in other comprehensive income before taxes          
 Healthcare   1,359,631    474,994 
 Pension and pension bonds   967,693    944,703 
 Education and severance   130,684    (242,679)
 Change in the effect of the asset ceiling   (329,824)   (50,059)
    2,128,184    1,126,959 

 

22.2Plan assets

 

Plan assets are represented in the resources provided to Pension Trusts, for payment of the pension liabilities relating to the obligations for monthly pension payments and bonds; that pertaining to health and education is under the responsibility of Ecopetrol. The allocation of trust resources and its yields cannot be changed or returned to the Company until all pension obligations have been fulfilled.

 

The composition by investment type is comprised as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Bonds issued by the Colombian Government   4,099,067    4,298,278    4,311,575 
Bonds of private entities   3,405,440    3,591,046    3,567,065 
Other bonds of public entities   790,601    825,970    864,917 
Bonds of foreign entities   300,181    230,772    196,404 
Other local currency   2,257,655    2,070,405    2,037,551 
Other foreign currency   429,828    480,712    389,416 
Variable yield   278,716    210,505    82,948 
Fair value of plan assets   11,561,488    11,707,688    11,449,876 
 Less asset ceiling   (379,884)   (50,059)   - 
    11,181,604    11,657,629    11,449,876 

 

F-47 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

The table below reflects the credit quality of issuers and counterparties in transactions involving the plan assets:

 

   2015   2014 
Credit quality of
issuers
  Local Rating   Global
Rating
   2015   Local Rating   Global
Rating
   Total 
AAA   7,566,394    31,068    7,597,462    9,034,715    79,131    9,113,846 
AA+   627,045    34,559    661,604    887,319    26,190    913,509 
AA   68,481    -    68,481    54,121    -    54,121 
AA-   18,316    36,761    55,077    18,038    15,509    33,547 
A   4,682    -    4,682    6,347    2,609    8,956 
A-                  10,206    -    10,206 
BBB+   31,164    165,651    196,815    -    155,420    155,420 
BBB   59,224    329,362    388,586    -    281,699    281,699 
BBB-   1,371,957    197,893    1,569,850    -    257,076    257,076 
BB+   5,199    23,800    28,999    1,407    -    1,407 
BB   -    22,572    22,572    -    -    - 
B+                  2,751    -    2,751 
CCC   1,035    -    1,035    1,052    -    1,052 
BRC1        -    -    2,007    -    2,007 
BRC1+   221,257         221,257    213,007    -    213,007 
F1+   43,351    -    43,351    63,364    -    63,364 
Unrated   701,717    -    701,717    595,720    -    595,720 
    10,719,822    841,666    11,561,488    10,890,054    817,634    11,707,688 

 

The fair value hierarchy of plan assets is comprised as follows:

 

   December 31,   December 31,   January 1, 
Fair value  2015   2014   2014 
Level 1   3,876,386    4,504,887    4,815,213 
Level 2   7,685,102    7,202,801    6,634,663 
    11,561,488    11,707,688    11,449,876 

 

The fair value of the plan assets is calculated using prices quoted in the relevant assets’ market. The Company obtains these prices through reliable financial data suppliers recognized in Colombia or abroad, depending on the investment.

 

For the securities issued in local currency, the fair value of the plan assets is calculated using information published by Infovalmer, a supplier of prices authorized by the Superintendency of Finance. According to its methodology, prices may be calculated based on market information at the valuation date or estimated based on historic inputs in accordance with the criteria established for the calculation of each of the prices.

 

The fair value is calculated based on the most representative market of the transactions carried out through electronic platforms approved and supervised by the regulator.

 

The estimated fair value is calculated for the investments that do not have sufficient information to estimate an average market price, by replicating the prices quoted for similar assets or prices obtained through quotations from stock brokers. This estimated price is also given by INFOVALMER as a result of the application of robust methodologies approved by the financial regulator and widely used by the financial sector.

 

22.3Actuarial assumptions

 

The following are the actuarial assumptions used in determining the present value of defined employee benefit obligations at December 31, 2015 and 2014 and January 1, 2014:

 

December 31, 2015  Pension  

Pension

bonds

   Medical   Education   Other benefits 
Discount rate   8.50%   8.50%   8.50%   7.75%   8.00%
Salary growth rate   4.25%   N/A    N/A    N/A    4.25%
Expected inflation rate   3.00%   3.00%   3.00%   3.00%   3.00%
Pension growth rate   3.00%   N/A    N/A    N/A    N/A 
Cost trend                         
 Short-term rate   N/A    N/A    3.50%   4.00%   N/A 
 Long-term rate   N/A    N/A    4.00%   4.00%   N/A 

 

December 31, 2014  Pension  

Pension

bonds

   Medical   Education   Other benefits 
Discount rate   7.50%   7.00%   7.50%   6.75%   7.50%
Salary growth rate   4.25%   N/A    N/A    N/A    4.25%
Expected inflation rate   3.00%   3.00%   3.00%   3.00%   3.00%
Pension growth rate   3.00%   N/A    N/A    N/A    N/A 
Cost trend                         
 Short-term rate   N/A    N/A    9.60%   9.40%   N/A 
 Long-term rate   N/A    N/A    4.00%   4.00%   N/A 

 

January 1, 2014  Pension  

Pension

bonds

   Medical   Education   Other benefits 
Discount rate   7.00%   6.25%   7.00%   6.50%   6.75%
Salary growth rate   4.50%   N/A    N/A    N/A    4.50%
Expected inflation rate   3.00%   3.00%   3.00%   3.00%   3.00%
Cost trend   N/A    N/A    10.40%   7.50%   N/A 

 

F-48 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

The cost trend is the projected increase for the initial year and the rate include the expected inflation rate.

 

The mortality table used for all calculations was ´Valid Annuitants” for men and women based on the experience gained for the period 2005-2008, of the Colombian Social Security Institute – ISS.

 

22.4Maturity of benefit obligation

 

The cash flow required for post-employment benefits liability is comprised as follows:

 

Period  Pension and
Pension bonds
   Other benefits   Total 
2016   752,287    318,469    1,070,756 
2017   794,341    316,343    1,110,684 
2018   813,537    319,015    1,132,552 
2019   829,656    320,929    1,150,585 
2020   847,469    325,153    1,172,622 
2021-2025   4,528,090    1,707,415    6,235,505 

  

22.5Sensitivity analysis

 

The sensitivity analysis on the Employee benefits liability below has been determined based on reasonably possible changes of the respective assumptions occurring at the end of the reporting period, while keeping all other assumptions as constant at December 31, 2015:

 

   Pension  

Pension

bonds

   Medical   Education   Other
benefits
 
 Discount rate                         
 -50 basis points   10,473,815    503,162    3,818,771    552,049    43,458 
 +50 basis points   9,469,073    466,168    3,390,058    527,183    40,761 
 Inflation rate                         
 -50 basis points   9,462,879    484,597    -    -    - 
 +50 basis points   10,477,600    483,633    -    -    - 
 Salary growth rate                         
 -50 basis points   -    -    -    -    40,530 
 +50 basis points   -    -    -    -    43,693 
 Cost trend                         
 -50 basis points   -    -    3,390,370    527,966    - 
 +50 basis points   -    -    3,817,007    551,131    - 

 

The Company performed a sensitivity analysis related to the interest rate variation on plan assets. See section 31 – Risk management.

 

23.Accrued liabilities and provisions

 

The following shows a breakdown of the changes in the different categories of accrued liabilities and provisions for the years ended December 31, 2015 and 2014:

 

F-49 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

   Asset 
retirement
obligation
   Litigations   Comuneros
provisions
   Environmental
contingencies
and others
   Total 
                     
Balance at December 31, 2014   4,281,107    299,551    551,497    705,916    5,838,071 
Additions (recoveries)   (60,813)   (188,962)   150,989    188,701    89,915 
Uses   (84,333)   (10,791)   -    (74,876)   (170,000)
Financial cost   238,876    -    -    2,417    241,293 
Foreign currency translation   89,793    -    -    5,905    95,698 
Transfers to assets held for sale   (12,261)   -    -    (5,369)   (17,630)
Balance at December 31, 2015   4,452,369    99,798    702,486    822,694    6,077,347 
Current   195,858    85,364    -    372,275    653,497 
Non-current   4,256,511    14,434    702,486    450,419    5,423,850 
Total   4,452,369    99,798    702,486    822,694    6,077,347 

 

   Asset 
retirement
obligation
   Litigations   Comuneros
provisions
   Environmental
contingencies
and others
   Total 
                     
Balance at January 1, 2014   3,456,184    537,440    445,364    479,358    4,918,346 
Additions (recoveries)   657,024    (210,153)   106,133    234,539    787,543 
Uses   (97,661)   (27,736)   -    (15,083)   (140,480)
Financial cost   217,164    -    -    -    217,164 
Foreign currency translation   48,396    -    -    7,102    55,498 
Balance at December 31, 2014   4,281,107    299,551    551,497    705,916    5,838,071 
Current   174,022    284,680    -    384,255    842,957 
Non-current   4,107,085    14,871    551,497    321,661    4,995,114 
Total   4,281,107    299,551    551,497    705,916    5,838,071 

  

23.1Asset Retirement Obligation

 

The Asset Retirement Obligation represents the Company's future obligation to restore environmental conditions to a level similar to that existing before the start of projects or activities, in accordance with that described in section 4.13. As these relate to long-term obligations, this liability projects expected future payments and is discounted to present value at a rate indexed to the Company's financial obligations, taking into account the timing and risks relating to this obligation. Compared with the previous year, there was an increase in the discount rate, which resulted in a recovery of the provision for Asset Retirement Obligation. The most significant asset retirement corresponds to Exploration and Production assets. The interest rate used for these assets was 7.28% in 2015 (2014 – 5.66%).

 

23.2Litigations

 

The following is a summary of the main legal proceedings, for which allowances have been recognized in the Consolidated Financial Statements due to a probable outflow of resources:

 

   December 31,   December 31,   January 1, 
Lawsuit  2015   2014   2014 
             
Compensation for damages for hydrocarbon easement in property near the Refineria de Cartagena.   11,019    11,019    - 
                
Labor proceeding of 2007 for the reassessment of salaries and social benefits to 232 Ecopetrol contractors. In the last quarter of 2015, the demanding files request for conciliation with a new amount of COP$9,338.   9,338    10,060    - 
                
Proceeding to reassess social, legal and extralegal benefit payments and monthly pension payments made under the saving incentive heading.   5,632    4,731    18,689 
                
Contributions to the solidarity and electric-power-generation income redistribution fund, pursuant to Act 142 of 1994.               
                
In order to protect their constitutional right of defense, Ecopetrol filed a proceeding (tutela) before the Consejo de Estado that ruled in favor of the company based on denial to the justice administration, therefore the court pronounced the annulment of all the all proceedings in the case. As a result the company considers that is unlikely a future outlay due to this process, and made a change in the accounting recognition for this year.   -    141,505    283,010 
                
By extension of the Garcero Association Contract, in defense of the public heritage and free economic competition.               
                
This process was favorable to Ecopetrol on second instance, generating a remote probability of future outflow of resources and the reversal of the provision in this respect.   -    77,592    155,184 

 

F-50 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

23.3Comuneros Provisions – Santiago de las Atalayas

 

It includes the injunctive relief ordered by the State Council in its decree of 1994 in the annulment action brought by the Ministry of Mines and Energy against Comuneros (community members) of Santiago de las Atalayas and Pueblo Viejo de Cusiana, corresponding to the attachment and seizure of the payments to be made by Ecopetrol for royalties, based on Royalty contracts declared null and void by the State Council in its ruling of 1999, in which it was ordered that such injunctive relief should be cancelled and that the attached and seized amounts should be handed over to the State – the Ministry of Mines. Ecopetrol has capacity as receiver. From such amount, COP$ 90,752 corresponds to the value initially recognized by Ecopetrol, as well as the valuation of the fund containing the resources; COP$611,734 corresponds to net interest income generated. In a ruling on December 12, 2012, notified by an edict on January 21, 2013, the State Council declared that the special plea for reconsideration filed by the Comuneros was dismissed. In November 2014 and December 2015, a new application was filed whereby Ecopetrol reiterated its request that the amounts seized in these proceedings be handed over, as the Company has paid the Nation and the beneficiary territorial entities the amount of total royalties incurred during the enforcement of the injunctive relief, and subsequently, these resources belong to Ecopetrol. It has not been obtained pronouncements to date. The amount of these resources are invested in cash and equivalents COP$2,654 (2014 - COP$3,085) and other financial assets for COP$699,832 (2014 - COP$548,413).

 

23.4Environmental contingencies and others

 

Relates mainly to obligations regarding environmental compensation for the use, harnessing or impact on natural resources in the context of environmental authorizations, as well as the mandatory 1% investment for water withdrawn directly from natural sources in accordance with the provisions of Law 99 of 1993 (Article 43) and Decree 1900 of 2006, in connection with the projects that Ecopetrol carries out in the regions.

 

23.5Legal proceedings not recognized

 

The following is a summary of the main contingent liabilities that have not been recognized in the Statement of Financial Position, since, according to evaluations performed by Company’s internal and external advisors, their occurrence is not probable:

 

   December 31,   December 31,   January 1, 
Lawsuit  2015   2014   2014 
Contributions to electric-power-generation pursuant to Act 142 of 1994.   219,944    219,944    219,944 
Compensation to third parties due to damage made by hydrocarbon spills   43,333    14,245    14,245 
Proceeding to reassess social, legal and extralegal benefit payments made under the saving incentive heading.   16,562    16,562    16,562 

 

F-51 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

23.6Detail of contingent assets

 

Below, there is a detail of the major assets contingencies, of which occurrence is possible:

 

   December 31,   December 31,   January 1, 
Claims  2015   2014   2014 
Nullity of Resolution No. 113 of 1971 from the Presidency of the Republic, in respect of the ownership of the subsoil to private parties known with the name of Santiago de Las Atalayas and Pueblo Viejo de Cusiana.   175,000    175,000    175,000 
Failure of the pipeline purchase order.   21,232    21,232    21,232 
Nullity of the administrative act that established a special contribution for public works contracts.   14,956    14,956    - 
Nullity of the administrative act that established a special contribution for public works contracts   13,214    13,214    - 
Breach of the contract for delivery of hydrotreatment units. During the last quarter of 2015 a conciliation agreement was presented which caused the process end with a balance in favor of Ecopetrol S.A. for an amount of COP$17,000   -    142,715    142,715 
                
Arbitration court formed to settle the differences between Offshore LLC against Ecopetrol and KNOC. During the last quarter of 2015, the Federal Court of Appeals in New York ruled in favor of Ecopetrol and KNOC process in relation to claims for post-closing contingencies related to the acquisition of Savia Peru.   176,885    176,885    - 

 

24.Derivative financial instruments

 

The following is a summary of the Derivative financial instruments and the hedging elements at December 31, 2015 and 2014 as well as the gain (losses) recognized in this period:

 

                Fair value 
             December 31,   December 31, 
Cash flow hedges - Instruments  Face value   Unit  Average price agreed (COP$/USD)  2015   2014 
                      
Forward - Exchange rate - purchase   14,880,659   USD  COP$2,623  Pesos/USD          
Forward - Exchange rate – sell   191,205,145   USD  COP$2,433      101,319    136,017 
Derivatives                        
Options - Exchange rate Collar   20,000,000   USD/month  Min: COP$ 2,050
Max:COP$2,678
  Pesos/USD   -    4,038 
        Total liabilities for hedging instruments   101,319    140,055 

 

F-52 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

   Gain (losses) recognized in profit or loss   Gain (losses) recognized in equity 
   2015   2014   2015   2014 
Derivative financial instruments                    
Commodities – Oil (Note 31.1)   (4,141)   -    212      
Exchange rate   (108,486)   (138,631)   (60,295)   - 
    (112,627)   (138,631)   (60,083)   - 

 

At December 31, 2015, Oleoducto Central S.A. entered into derivative contracts, which purpose is to mitigate the exchange rate volatility in the cash flow required for short-term operations. The mitigation of these risks is made through the purchase/sale of US Dollars in non-delivery forward contracts.

 

The hierarchy of fair value of these instruments is level 2 which was calculated based on observable inputs, using the forward rate methodology.

 

25.Equity

 

The main components of equity are comprised as follows:

 

25.1Subscribed and paid-in capital

 

Ecopetrol’s authorized capital amounts to COP$36,540,000, and is comprised of 60,000,000,000 ordinary shares, 41,116,694,690 of such shares have been subscribed represented by 11.51% (4,731,905,873 shares) of natural and non-government entities and 88.49% (36,384,788,817 shares) held by Government entities. The value of unsubscribed capital shares amounts to COP$11,499,933 comprised by 18,883,305,310 shares. At December 31, 2015, subscribed and paid-in capital amounts to COP$25,040,068 (December 31 and January 1, 2014 COP$ 10,279,175). There are no potentially dilutive instruments.

 

On March 26, 2015, the General Stockholders’ Meeting approved the capitalization of occasional reserves of Ecopetrol S.A. for COP$14,760,893 through the mechanism of increasing the face value. This capitalization of reserves did not modify materially the number of ordinary shares registered.

 

25.2Additional paid-in capital

 

It mainly corresponds to: (i) surplus with respect to its nominal value derived from the sale of shares upon capitalization in 2007, in the amount of COP$4,457,701, (ii) COP$31,351, the value generated by the process of placing the shares on the secondary market, arising from the calling of guarantees from debtors in arrears, according to the provisions of Article 397 of the Code of Commerce, (iii) to the surplus over nominal value arising from the sale of shares awarded in the second round, which took place in September 2011, in the amount of COP$2,118,492, and (iv) additional paid-in capital receivable for COP$155.

 

25.3Equity reserves

 

The balance of equity reserves is comprised as follows:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Legal reserve   5,227,726    5,271,104    5,033,539 
Occasional reserve   488,090    12,938,996    9,956,268 
Tax and mandatory reserves   780,228    231,698    397,873 
Total   6,496,044    18,441,798    15,387,680 

 

The following shows the balance and a breakdown of the changes in equity reserves according to the General Stockholders Meeting approved in 2015 and 2014:

 

   December 31,   December 31, 
   2015   2014 
Opening balance   18,441,798    15,387,680 
Release of occasional reserves   (12,823,783)   (10,161,138)
Appropriation of reserves   15,638,922    13,215,256 
Capitalization of reserves   (14,760,893)   - 
Closing balance   6,496,044    18,441,798 

 

F-53 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

  

Legal reserve

 

The Code of Commerce establishes the appropriation obligation of 10% of net income to the legal reserves until the legal reserves are equal to 50% of the subscribed capital. The legal reserve can be used to offset losses or for distribution in the event of a Company’s liquidation.

 

Occasional reserves

 

This corresponds to the appropriation of earnings ordered by the Stockholders’ meeting to carry out new explorations and future investments, as well as unrealized profits between group companies. On March 26, 2015, The Ecopetrol Stockholders’ Meeting approved the release of occasional reserves of COP$12,823,873, the appropriation of the occasional reserves of COP$15,167,878 and the capitalization of occasional reserves for COP$14,760,893, through the mechanism of face value increase. The appropriation of occasional reserves by the subsidiaries was COP$471,044 in 2015.

 

On March 26, 2014, The Ecopetrol Stockholders’ Meeting approved the release of occasional reserves of COP$10,161,138, the appropriation of the occasional reserves of COP$12,802,791. The appropriation of occasional reserves by the subsidiaries was COP$412,465 in 2014.

 

Tax and mandatory reserves

 

The Colombian tax regime contemplates the appropriation of the period’s profits equivalent to 70% when the value of the depreciation claimed for tax purposes exceeds the accounting depreciation. This reserve may be released to the extent that the depreciations subsequently accounted exceed those annually claimed for tax purposes, or the assets that generated the higher value deducted are sold.

 

In addition, Decree 2336 of 1995 set out the obligation to establish a reserve for valuation of investments. The profits generated at the closing of the accounting period as a consequence of the application of special valuation systems at market prices and that have not been made on behalf of the Company, will be taken to a reserve.

 

25.4Retained earnings and payment of dividends

 

The following shows the balance and a breakdown of the changes in retained earnings:

 

   December 31,   December 31, 
   2015   2014 
Opening balance   7,713,612    16,411,555 
Income (loss) attributable to owners of Ecopetrol   (7,193,859)   5,046,517 
Appropriation of reserves   (2,815,139)   (3,054,118)
Dividends declared   (5,468,521)   (10,690,342)
Closing balance   (7,763,907)   7,713,612 

 

The company distributes dividends based on its separate financial statements prepared under Colombian GAAP.

 

On the results of the 2014 year end, the General Stockholders Meeting approved the distribution of an ordinary dividend per share of COP$133 attributable to the owners of Ecopetrol. In June, 2015, The Company paid to the minority stockholders COP$629,344 and COP$4,149,000 to the majority of stockholders. Dividends declared to the majority shareholder in 2015 payable at December 31, 2015 amounted to COP$690,177.

The dividends paid attributable to non-controlling interest amounted to COP$715,053 in 2015 and COP$516,332 in 2014.

 

In 2014, ordinary dividends of COP$227 per share were paid and extraordinary dividends for COP$33 per share, for a total dividend of COP$260 per share, which were paid in their entirety at December 31, 2014.

 

F-54 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

25.5Other comprehensive income attributable to owners of the Company

 

The following is a breakdown of other comprehensive income attributable to owners of the Company:

 

   December 31,   December 31, 
   2015   2014 
Gain of defined benefit obligation (Note 22)   2,148,395    743,793 
Gain (loss) on equity instruments measured at fair value (1)   (49,881)   76,435 
Cash flow hedging - Future crude oil exports (Note 31)   (217,291)   - 
Cash flow hedging – Derivative financial instruments - Exchange rate   (43,590)   - 
Foreign currency translation   8,949,728    3,160,521 
Others   58,643    - 
    10,846,004    3,980,749 

 

(1)During the third quarter of 2015, it was classified to profit or loss COP$19,405 proceeds from the realization of valuations at market prices accumulated in equity from assets held for sale - Empresa de Energía de Bogota (Note 10).

 

26.Sales revenue

 

The following is a breakdown of sales revenue for the years ended December 31:

 

   2015   2014 
National sales          
Mid-distillates   10,215,224    11,983,455 
Gasoline   6,128,208    6,394,422 
Services   4,435,274    3,778,073 
Natural gas   1,845,345    1,346,625 
Plastic and rubber   724,392    667,563 
Crude   491,279    1,213,718 
Asphalts   461,188    459,072 
L.P.G. and propane   335,494    426,450 
Other products   988,346    1,001,321 
    25,624,750    27,270,699 
Recognition of price differential (1)   441,871    485,409 
    26,066,621    27,756,108 
Foreign sales          
Crude   21,181,265    30,835,510 
Fuel oil   2,166,469    3,921,703 
Trading of crude   1,309,196    1,486,060 
Plastic and rubber   1,096,730    975,282 
Natural gas   182,950    423,461 
Gasoline and turbo fuel   93,125    127,090 
Diesel   81,982    179,738 
Cash flow hedging – Reclassification to profit or loss (Note 31)   7,646    - 
Others   161,287    266,936 
    26,280,650    38,215,780 
Total sales revenue   52,347,271    65,971,888 

 

1)Corresponds to the application of Decree 1880 of September 2014 and Resolution 180522 of 2010, which defined the procedure for price differentials (value generated by the difference between the parity price and the regulated price, which can be positive or negative). See section 4.16 – Revenue recognition, for more details.

 

F-55 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

27.Cost of sales before impairment of non-current assets

 

The following is the detail of cost of sales according to their function, for the years ended December 31:

 

   2015   2014 
Variable costs          
Imported products (1)   12,935,878    13,264,700 
Depreciation, depletion and amortization   5,166,455    5,114,053 
Hydrocarbon purchases - ANH (2)   3,741,010    6,630,309 
Purchases of crude in association and concession   1,928,938    3,293,594 
Hydrocarbons transportation services   1,380,733    1,548,115 
Purchases of other products and gas   703,163    1,021,327 
Services contracted in associations   563,032    612,013 
Gas royalties in cash (3)   481,029    399,752 
Electric power   424,920    408,248 
Processing materials   366,454    349,953 
Others   (322,547)   98,904 
    27,369,065    32,740,968 
Fixed costs          
Maintenance   2,334,130    2,646,832 
Labor cost   1,542,701    1,369,654 
Depreciation and amortization   1,433,263    1,144,437 
Services contracted in associations   1,415,422    1,674,322 
Services contracted   1,301,094    1,578,918 
Taxes and contributions   461,624    607,494 
General costs   461,994    441,718 
Materials and operating supplies   435,238    500,934 
Hydrocarbons transportation services   147,733    74,976 
Non-capitalized project costs   92,252    194,875 
    9,625,451    10,234,160 
    36,994,516    42,975,128 

 

(1)Mainly corresponds to purchases of diesel and diluent agents to facilitate the transportation of heavy crude oil.

 

(2)Corresponds mainly to the purchases of crude royalties that Ecopetrol makes from the National Hydrocarbons Agency (Agencia Nacional de Hidrocarburos or ANH by its acronym in Spanish) derived from national production, by both the Company in direct operation and third parties.

 

(3)By means of Resolution 877 of September 2013, the National Hydrocarbons Agency established that, as from January 1, 2014, it will collect payment in cash, not in kind, for royalties generated by gas production.

 

28.Administration, operation and project expenses

 

The following is the detail of administration, operation and project expenses, according to their function, for the years ended December 31:

 

   2015   2014 
Administration expenses          
Taxes (1)   730,841    102,028 
Labor expenses   491,748    463,836 
General expenses and other   393,971    410,288 
Depreciation and amortization   84,425    54,883 
    1,700,985    1,031,035 
Operation and project expenses          
Exploration expenses   1,584,249    2,576,294 
Commissions, fees, freights and services   878,259    1,244,045 
Corporate projects   456,159    269,495 
Taxes   348,871    449,824 
Labor expenses   309,021    266,362 
Maintenance   181,630    241,313 
Fee for regulatory entities   77,909    108,263 
Depreciation and amortization   86,215    103,834 
Various   111,955    260,895 
    4,034,268    5,520,325 

 

(1)It mainly includes the recognition of wealth tax. See Note 9 – Current tax assets and liabilities.

 

F-56 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

29.Impairment of non-current assets and other operating income and (expenses)

 

The following is the detail of impairment of non-current assets and other operating income and expenses, for the years ended December 31:

 

Impairment of non-current assets details:

 

   2015   2014 
Investments in associates and joint ventures (Note 14)   (588,144)   (114,734)
Goodwill (Note 19)   (266,900)   - 
Property, plant and equipment (Notes 15-18)   (4,144,754)   (1,491,809)
Natural and environmental resources (Notes 16-18)   (2,865,077)   (694,720)
Intangibles (Note 17-18)   -    (3,304)
    (7,864,875)   (2,304,567)

 

Other operating income and (expenses) detail:

 

   2015   2014 
Deferred BOMT’s income (1)   193,197    140,372 
Compensation received   29,848    24,648 
Earnings from the sale of materials and property, plant and equipment   50,116    8,426 
Loss on fixed assets and natural resources disposals   (43,372)   (119,804)
Recovery of legal processes accrual (Note 23)   205,879    203,688 
Current Assets Impairment expenses   (2,858)   (24,784)
Gas pipeline availability under BOMT’s contracts   (124,957)   (102,916)
Other income (expenses), net   70,685    178,564 
    378,538    308,194 

 

(1)BOMT = Build, Operate, Maintain and Transfer contracts

 

30.Finance result, net

 

The following is the detail of finance results, net for the years ended December 31:

 

   2015   2014 
Finance Income          
Yield and interest   293,507    286,527 
Valuation of financial assets (1)   164,614    57,807 
Gain on sale of investments   72,339    - 
Dividends   91,464    53,202 
Gain from hedging transactions   -    2,282 
    621,924    399,818 
Finance costs          
Interest (2)   (1,768,618)   (754,276)
Other liabilities financial costs (3)   (627,827)   (651,055)
Finance expense from financial assets   (167,869)   (57,640)
Loss from hedging transactions   (108,486)   (140,913)
Other finance expenses   (45,614)   (36,410)
    (2,718,414)   (1,640,294)
Foreign exchange loss gain, net (2)   (5,566,614)   (2,270,193)
Finance result, net   (7,663,104)   (3,510,669)

 

(1)Includes fair value measured of other financial assets.
(2)Interest was capitalized during the period to natural resources and property, plant and equipment for COP$744,426 (2014 – COP$640,698). Foreign exchange gain was COP$21,813,720 in 2015 (2014 - COP$27,380,334) and Foreign exchange loss was COP$7,360,782 in 2015 (2014 - COP$9,630,975)

 

F-57 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

(3)Includes finance cost of asset retirement obligations and Post-employment benefits liabilities.

 

31.Risk management

 

31.1Commodity price risk

 

Ecopetrol´s business depends substantially on international prices for crude oil and refined products. The prices for these products are volatile; and drastic changes could adversely affect the Company business prospects and results of operations.

 

A large proportion of Ecopetrol´s revenues come from sales of crude oil, natural gas and refined products. These products are indexed to international reference prices such as the ICE Brent Index. Consequently, fluctuations in those international indexes have a direct effect on the financial condition and Company´s results of operations.

 

Prices of crude oil, natural gas and refined products have historically fluctuated as a result of a variety of factors including, among others, competition within the oil and natural gas industry; changes in international prices of natural gas and refined products; long-term changes in the demand for crude oil, natural gas and refined products; regulatory changes; changes in the cost of capital; adverse economic conditions; transactions in derivative financial instruments related to oil and gas and development or availability of alternative fuels.

 

The Ecopetrol Business Group has a policy approved by the Board of Directors that allows it to use derivative financial instruments in the organized market or over the counter (OTC) to cover itself from the risk of price fluctuations of crude oil and refined products associated to physical transactions. The Company has established appropriate process to handle risk that include constant monitoring of physical and financial market to identify risks in order to subsequently prepare and execute hedging strategies.

 

During June 2015, the Company entered into a short-term derivative transaction with the purpose of mitigating in a 1-million Castilla crude oil barrels export, the exposure to the risk of price index different from the benchmark of the Company’s international trade strategy. This transaction was settled in July 2015 with a loss of COP$4,141.

 

As of December 31, 2015, there is an open position regarding a price hedging transaction for the export of Napo Crude up to 225,000 barrels, with settlement in January 2016. As of December 31, it was recognized in other comprehensive income, net of taxes COP$212.

 

31.2Exchange rate risk

 

The group mainly operates in Colombia and makes sales in the local and international markets. We are exposed to the exchange rate risk that arises from various foreign currency exposures due to commercial transactions and assets and liabilities held in foreign currency. The impact of fluctuations in exchange rates, especially the Pesos/USD rate, on operations has been material.

 

The USD /pesos exchange rate has fluctuated during the last several years. The peso depreciated 37.3% on average in 2015 and 7.1% in 2014. The exchange rates were COP$3,149.47, COP$2,392.46 and COP$ 1,926.83 at December 31, 2015, 2014 and 2013, respectively.

 

When the Colombian peso appreciates in comparison with U.S. dollar, export revenues decrease when translated into Pesos. However, imported goods, oil services and interest on external debt denominated in U.S. dollars become less expensive for us. Conversely, when the Colombian peso depreciates in comparison with the U.S. dollar, revenues from exports, when translated into Pesos, increase, and imports and external debt service become more expensive.

 

The following table sets out the carrying values for financial assets and liabilities denominated in foreign currencies at the consolidated level:

 

   December 31,   December 31,   January 1, 
USD COP$ Million  2015   2014   2014 
Cash and cash equivalents   970    1,905    1,528 
Other financial assets   381    438    1,009 
Trade receivables and payables, net   (546)   (463)   (439)
Loans and borrowings   (14,634)   (11,638)   (7,921)
Net liability position   (13,829)   (9,758)   (5,823)

 

F-58 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

Of the total net liability position, approximately 31% relates to financial assets and liabilities for companies that have the Colombian peso as their functional currency, whose value has affected results for the financial year. 69% of the net position relates to monetary assets and liabilities for group companies that have the dollar as their functional currency and non-derivate hedging instruments from Ecopetrol S.A., whose value is recognized in other comprehensive income.

 

The Company’s risk management strategy involves the use of non-derivative financial instruments related to cash flow hedges for future exports, in order to minimize exposure to currency rate risk.

 

31.2.1Cash Flow Hedge for Future Company Exports

 

Ecopetrol S.A. is exposed to foreign exchange risk given that a high percentage of its crude export revenues are denominated in U.S. dollars. In recent years, the company has acquired long-term debt for investment activities in the same currency that projects receiving the cash flow of its export revenues. This situation creates a natural hedge relationship due to the fact that the risks generated by the foreign exchange difference of export revenues to Ecopetrol´s functional currency (Colombian pesos) are naturally hedged with the foreign exchange valuation risks of the long-term debt in U.S. dollars, aligned with the company’s risk management strategy.

 

With the objective of presenting in the Financial Statements the effect of the mentioned natural hedge between exports and debt, understanding that the exchange rate risk materializes when the exports are made, on October 1°, 2015, the Board of Directors designated USD 5,440 million of Ecopetrol S.A’s debt as hedge instrument of its future export sales for the period 2015- 2023, in accordance with IAS 39 – Financial instruments: recognition and measurement.

 

Hedge accounting records the impact of foreign exchange gains/losses on the hedging instrument on statement of profit and loss effectively at the time of realization of the hedged risk. For this to happen, every month when the foreign currency debt is translated to Colombian pesos at the closing exchange rate, the effects on foreign exchange differences are recognized as part of the other comprehensive income. Once the hedged operation occurs and revenue is recognized, the cumulative exchange differences held within in other comprehensive income is reclassified to profit or loss statement, impacting operating income and EBITDA.

 

The following shows the movement of these non-financial hedging instruments:

 

   USD  (millions) 
Hedging instruments designated at October 1°, 2015   5,376 
Reassignment of hedging instruments   277 
Realized exports   (277)
Hedging instruments at December 31, 2015   5,376 

 

The expected reclassification of the exchange differences accumulated in other comprehensive income to profit and loss state is as follows:

 

Year  Amount  

Income tax

(Average 37%)

   Net 
2016   73,404    (27,150)   46,254 
2017   72,856    (26,947)   45,909 
2018   70,694    (26,148)   44,546 
2019   55,511    (20,532)   34,979 
2020   21,223    (7,850)   13,373 
2021   17,125    (6,334)   10,791 
2022   17,125    (6,334)   10,791 
2023   16,898    (6,250)   10,648 
    344,836    (127,545)   217,291 

 

This has been effective since the start date of the hedge for future exports, according to the effectiveness tests performed.

 

F-59 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

31.2.2Sensitivity analysis for exchange rate risk

 

The following table shows the impact that a variation of 1% and 5% in the exchange rate of the Colombian peso vs the United States of America dollar would have on the assets and liabilities held in such currency at December 31, 2015:

 

Variation in the exchange

rate

  

Effect in income

before taxes (+/-)

  

Effect in other comprehensive

income (+/-)

 
 1%   136,215    299,326 
 5%   681,073    1,496,628 

 

Sensitivity analysis includes only monetary assets and monetary liabilities held in foreign currency at the closing date and the effect of the Cash Flow Hedge for Future Company Exports.

 

31.3Credit risk

 

Credit risk is the risk that the Company may suffer losses as a consequence of the breach of contracts for purchase and sale of crude oil, gas, refined and petrochemical products and transportation services, in addition to the financial institutions in which it keeps investments or the counterparties with which it has contracted derivative financial instruments.

 

In performance of the sale process of crude oil, gas, refined and petrochemical products and transportation services, the Company may be exposed to credit risk in the event that customers fail to comply with their payment obligations. Risk management has designed mechanisms and procedures that have permitted the Company to minimize the probability of materialization, thus safeguarding the Company’s cash flow.

 

The Company performs a continuous analysis of the financial strength of its counterparties, which implies their classification according to their risk level and financial supports in the event of a cessation of payments. In addition, a constant monitoring is made of the national and international market conditions in order to establish early alerts of major changes that may have an impact on the timely payment of obligations from customers of the Company.

 

For the bad debts, an individual analysis is performed that allow us analyzing individually the situation of each customer and thus define the applicable allowance to be established, such as age of receivables. The group carries out the administrative and legal actions necessary to recover past due accounts receivable, as well as the collection of interest from customers who do not comply with payment policies.

 

Credit quality of financial assets

 

Following the promulgation of Decree 1525 of 2008, which provides general rules on investments for public entities, Ecopetrol S.A.’s management established guidelines for our investment portfolios.  These guidelines determine that investments in Ecopetrol S.A.’s U.S. dollar portfolio are generally limited to investments of our excess cash in fixed-income securities issued by entities rated A or higher in the long term and A1/P1/F1 or higher in the short term (international scale) by Standard & Poor’s Ratings Services, Moody’s Investors Service or Fitch Ratings.  In addition, Ecopetrol S.A. may also invest in securities issued or guaranteed by the U.S. government or Colombian government, without regard to the ratings assigned to such securities.  In Ecopetrol S.A.’s Peso portfolio, it must invest our excess cash in fixed-income securities of issuers rated AAA in the long term, and F1+/BRC1+ in the short term (local scale) by Fitch Ratings Colombia or BRC Standard & Poor’s.  In addition, Ecopetrol S.A. may also invest in securities issued or guaranteed by the Colombian government without rating restrictions.

 

In order to diversify risk in our Peso portfolio, Ecopetrol S.A. does not invest more than 10% of the excess of cash in one specific issuer.  In the case of our U.S. dollar portfolio, it does not invest more than 5% of the excess of cash in one specific issuer in the short term (up to 1 year), or 1% in the long term. The Company complied with this policy.

 

At December 31, 2015, the business group does not have significant concentrations of credit risk. The following is the analysis of aging of customer portfolio in arrears but not impaired, at December 31, 2015:

 

   December 31, 
   2015 
Less than 3-month   71,791 
Between 3- and 6- month   4,862 
More than 6-month   116,849 
Total   193,502 
31.4Interest rate risk

 

Interest rate risk arises from Ecopetrol´s exposure to changes in interest rates, as we have fixed floating-rate instruments in Ecopetrol´s investment portfolio and issuances of floating rate debt linked to LIBOR, DTF and IPC rates. Thus, volatility in interest rates may affect the fair value and cash flows related to Company´s investments and floating rate debt.

 

F-60 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

At December 31, 2015, approximately 31% of Company total indebtedness consisted of floating rate debt. If market interest rates rise, financing expenses will increase and could have an adverse effect on results of operations and financial condition.

 

Ecopetrol S.A. controls the exposure to interest rate risk by establishing limits to its effective duration, Value at Risk and Tracking Error.

 

The trust funds linked to Ecopetrol S.A.’s pension obligations (PAP) are also exposed to changes in interest rates, as they include fixed- and floating-rate instruments that are marked to market. Colombian regulation for pension funds, as stipulated in the Decree 941 of 2002 and Decree 1861 of 2012, indicates that they have to follow the same regime as the regular obligatory pension funds in their moderate portfolio.

 

The following table provides information about the sensitivity of Company´s results and other comprehensive income, for the next 12 months, to variations in interest rate of 100 basis points:

 

   Financial liabilities   Financial assets   Plan assets 
Variation in interest rate  (Financial result)   (Financial result)   (Other comprehensive income) 
+ 100 basis points   (159,051)   (24,742)   (281,926)
-  100 basis points   148,408    24,742    281,926 

 

Sensitivity analysis of discount rates on pension plans is shown in its corresponding note of Labor and pension plan obligations.

 

31.5Liquidity risk

 

The ability to access the capital necessary to finance the Company´s investment plans on terms acceptable to us, can be limited due to deterioration in market conditions. A new financial crisis could worsen the risk perception in the emerging markets.

 

Risks related to Colombia’s political and regional environment could also make it more difficult to access international capital markets. These conditions, along with significant write-offs in the financial services sector and the re-pricing of credit risk, can make it difficult for us to obtain funding for capital needs on favorable terms. As a result, we may be forced to revise the timing and scope of these projects as necessary to adapt to existing market and economic conditions, or access the financial markets on terms less favorable, therefore negatively affecting the Company´s results of operations and financial condition.

 

Liquidity risk is managed in accordance with The Company´s policies aimed at ensuring that there are sufficient net funds to meet the Company's financial commitments within its maturity schedules, with no additional costs. The main method for the measurement and monitoring of liquidity is cash flow forecasting.

 

The following is a summary of the maturity of financial liabilities at December 31, 2015. The amounts disclosed in the table are the contractual undiscounted cash flows. The payments in foreign currency were restated taking a constant exchange rate of COP$ 3,149.47 Colombian pesos per dollar. Consequently, these amounts may not reconcile with the amounts disclosed on the consolidated statement of financial position.

 

   Up to 1 year   1 - 5 years   5-10 years   > 10 years   Total 
Loans (Principal and   Interests)   4,888,992    27,408,454    23,396,829    25,878,137    81,572,412 
Trade and other accounts  payables   7,757,277    500,714    -    3    8,257,994 
Derivative financial instruments   101,319    -    -    -    101,319 
Total   12,747,588    27,909,168    23,396,829    25,878,140    89,931,725 

 

31.6Capital management

 

The main objective of Ecopetrol’s Capital Management is to ensure a financial structure that will optimize the Company’s cost of capital, maximizes the returns to its shareholders and allows access to financial markets at a competitive cost to cover its financing needs.

 

F-61 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

The leverage index at the relevant periods is comprised as follow:

 

   December 31,   December 31,   January 1, 
   2015   2014   2014 
Loans and borrowings (Note 20)   53,223,338    35,041,628    22,693,263 
Cash and cash equivalents (Note 6)   (6,550,450)   (7,618,178)   (8,805,090)
Other financial assets not restricted (Note 11)   (885,547)   (933,406)   (1,680,242)
Net financial debt   45,787,341    26,490,044    12,207,931 
Equity (Note 25)   43,100,963    48,534,228    49,864,569 
Leverage (1)   51.51%   35.31%   19.67%

 

(1)Net financial debt / (Net financial debt + Equity)

 

32.Related parties

 

Balances with associated companies and joint ventures as of December 31, 2015, December 31 and January 1, 2014 are as follows:

 

   Accounts
receivables
   Other assets   Accounts payable   Loans 
Joint ventures                    
Equion Energía Limited   64,583    28,668    62,861    45,913 
Ecodiesel Colombia S.A.   -    -    22,243    - 
Associates                    
Serviport S.A.   141    -    2,359    - 
Balance at December 31, 2015   64,724    28,668    87,463    45,913 

 

   Accounts
receivables
   Other assets   Accounts payable   Loans 
Joint ventures                    
Equion Energía Limited   75,561    9,338    84,006    36,728 
Ecodiesel Colombia S.A.   -    -    20,308    - 
Associates                    
Serviport S.A.   -    -    3,506    - 
Balance at December 31, 2014   75,561    9,338    107,820    36,728 

 

   Accounts
receivables
   Other assets   Accounts payable   Loans 
Joint ventures                    
Equion Energía Limited   164,711    15,558    102,529    578,423 
Ecodiesel Colombia S.A.   -    -    22,890    - 
Associates                    
Serviport S.A.   -         1,674    - 
Balance at January 1, 2014   164,711    15,558    127,093    578,423 

 

Outstanding amounts are not guaranteed and will be settled in cash. No guarantees have been granted or received. No expense has been recognized in the current period or in previous periods in respect to uncollectable or doubtful accounts related to amounts due by related parties.

 

The most significant transactions with related parties for the years ended December 31, 2015 and 2014 are comprised as follows:

 

   2015   2014 
Joint ventures                    
Equion Energía Limited   515,968    190,158    908,357    79,264 
Ecodiesel Colombia S.A.   7,245    267,647    3,840    220,834 
Total transactions   523,213    457,805    912,197    300,098 

 

32.1Key Executives Management

 

Based on a resolution adopted at the annual shareholders’ meeting in 2012, compensation to directors is the equivalent of four to six minimum monthly wage salaries, which totals approximately COP$3,700 for 2014 and COP$3,900 for 2015. Fees for attendance at virtual meetings are set at 50% of the face-to-face meeting fee. The Board of Directors is not subject to any variable remuneration.

 

F-62 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

The total compensation paid to Directors, executive officers and senior management during the year ended in December 31, 2015 amounted to COP$6,690 (2014 - COP$9,058). The Directors are not eligible to receive pension and retirement benefits from us. The total amount set aside to provide pension and retirement benefits to our eligible executive officers amounted to COP$10,341 (COP$13,958).

 

As of December 31, 2015, the following Key management Executives owned less than 1% of the outstanding shares of Ecopetrol S.A., as follows:

 

Key management executive   % Shareholding
Joaquín Moreno Uribe    <1% of outstanding shares
Roberto Steiner Sampedro   <1% of outstanding shares
Mauricio Cárdenas S   <1% of outstanding shares
Hector Manosalva Rojas   <1% of outstanding shares
Juan Carlos Echeverry   <1% of outstanding shares

 

32.2Government related parties

 

Colombian Government holds control of Ecopetrol S.A. with a stock ownership of 88.49%. The most significant transactions with governmental entities are comprised as follows:

 

a)Purchases of crude oil from the National Hydrocarbons Agency ( Agencia Nacional de Hidrocarburos – ANH)

 

Because of the business nature, the company has a direct relationship with ANH, an entity which operates under the Ministry of Mines and Energy rules, of which objective is to manage the oil and gas reserves and resources owned by the Nation.

 

Ecopetrol S.A. purchases the crude oil that the ANH receives from all producers in Colombia at the prices set in accordance with a jointly established formula, which reflects the export sale prices (crude oils and products), adjustment to the API gravity quality, sulfur content, transportation rates from the wellhead to the ports of Coveñas and Tumaco, refining process cost and a commercialization rate. This contract was extended to June 30, 2016.

 

At December 2013, the Company commercialized, on behalf of the ANH, the natural gas received by the latter in kind from the producers. Since January 2014 the ANH receives the royalties in cash for the production of natural gas.

 

The purchase value of oil and gas from the AHN is detailed in Note 27-Cost of sales.

 

Additionally Ecopetrol, like other oil companies, takes part in "rounds" for the allocation of exploration blocks in Colombia, without implying special treatment for Ecopetrol on account of it being an entity whose majority shareholder is the Ministry of Finance.

 

b)Price differential

 

Regular gasoline and diesel sale prices are regulated by the National Government. In this case, there are differentials between the volume reported by the Companies at the time of the sale and the difference between the parity price and the benchmark price, where the parity price is that corresponding to the daily motor gasoline and diesel prices observed during the month. These differentials may be in favor or against the producers. The value of this differential is detailed in Note 26 - Revenue.

 

c)Department of National Tax and Customs

 

Ecopetrol, just like any other company in Colombia, has tax obligations that it must comply with in respect of this entity, and Ecopetrol does not have any other kind of association or commercial relationship with it. For more information see Note 9 - Tax.

 

d)Comptroller General of the Republic

 

Ecopetrol, just like any other state entity in Colombia, is obliged to comply with the requirements set out by this control entity and make an annual payment to this entity on account of a maintenance fee. Ecopetrol does not have any other kind of association or commercial relationship with this entity.

 

F-63 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

33.Joint Operations

 

The Company carries out exploration and production operations through Exploration and Production (E&P) Contracts, Technical Evaluation (TEA) Contracts and Agreements signed with the National Hydrocarbons Agency or ANH, as well as through Partnership Contracts and other types of contracts. The main joint operations in 2015 are as follows:

 

Contracts in which Ecopetrol is not the operator:

 

Partners   Contract   Type   Geographic area
of Operations
  % Participation
ANADARKO   K2   Production   US   9%
    BM-C-29.   Exploration   Brazil   50%
    Fuerte Norte, Fuerte Sur, Purple Angel, Col-5 y URA-4   Exploration   Offshore South Caribbean   50%
APACHE   Parmer   Exploration   US   30%
EQUION ENERGIA LIMITED   Niscota   Exploration   Colombia   20%
    Piedemonte   Production   Colombia   50%
MURPHY OIL   Dalmatian North   Production   US   30%
    Dalmatian South   Exploration   US   30%
    Sea Eagle   Exploration   US   50%
NOBLE ENERGY   Gunflint   Exploration   US   32%
PERENCO COLOMBIA LIMITED   Casanare   Production   Colombia   64%
    Corocora   Production   Colombia   28%
    Estero   Production   Colombia   7%
    Garcero   Production   Colombia   15%
    Orocue   Production   Colombia   23%
REPSOL   Leon   Exploration   US   40%
    BM-ES-29.   Exploration   Brazil   30%
    Ronda Caribe RC-11 Y RC-12   Exploration   Offshore North Caribbean   50%
SHELL   Deep Rydberg/Aleatico   Exploration   US   29%
    SIN OFF - 7   Exploration   Offshore South Caribbean   35%
OCCIDENTAL ANDINA LLC   Chipiron   Production   Colombia   30%
    Cosecha   Production   Colombia   30%
    Cravo norte   Production   Colombia   50%
    Rondon   Production   Colombia   50%

 

F-64 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

Partners   Contract   Type   Geographic area of
Operations
  % Participation
CHEVRONTEXACO PETROLEUM   Guajira   Production   Colombia   57%
COMPANY   CE-M-715_R11   Exploration   Brazil   50%
MANSAROVAR ENERGY COLOMBIA LTD   Nare   Production   Colombia   50%
META PETROLEUM CORP   Quifa   Production   Colombia   30%
SUCURSAL (1)   Rubiales   Production   Colombia   58%
LEWIS ENERGY COLOMBIA INC   SSJN1   Exploration   Colombia   50%
PETROBRAS   PAMA-M-187.   Exploration   Brazil   30%
    PAMA-M-188.   Exploration   Brazil   30%
    PAMA-M-222.   Exploration   Brazil   30%
    PAMA-M-223.   Exploration   Brazil   30%
    BM-C-44.   Exploration   Brazil   38%
    BM-S-74.   Exploration   Brazil   13%
HESS   BM-ES-30.   Exploration   Brazil   30%
ONGC   BM-S-73.   Exploration   Brazil   13%
VANCO   BM-S-63.   Exploration   Brazil   30%
    BM-S-71.   Exploration   Brazil   30%
    BM-S-72.   Exploration   Brazil   30%
ONGC VIDESH LIMITED SUCURSAL COLOMBIA   Ronda Caribe RC-10   Exploration   Offshore North Caribbean   50%
PETROBRAS, REPSOL & STATOIL   Tayrona   Exploration   Offshore North Caribbean   30%
REPSOL & STATOIL   TEA GUA OFF-1   Exploration   Offshore North Caribbean   50%

 

(1)In March, 2015, Ecopetrol and Pacific Rubiales Energy announced that they have agreed not to extend the Rubiales risk participation and Piriri joint venture contracts that expire in 2016. As a result, Ecopetrol will obtain a 100% interest in both fields as of June, 2016 and will operate directly.

 

Contracts in which Ecopetrol is the operator:

Partners   Contract   Type   Geographic
area of
Operations
  % Participation
EXXONMOBIL EXPLORATION COLOMBIA   VMM29   Exploration   Colombia   50%
MAUREL & PROM COLOMBIA   CPO-17   Exploration   Colombia   50%
TALISMAN COLOMBIA OIL &   CPO9   Exploration   Colombia   55%
GAS LTD   CPO9 - AKACIAS   Production   Colombia   55%
OCCIDENTAL ANDINA LLC   La Cira Infantas   Production   Colombia   56%
ONGC VIDESH LIMITED SUCURSAL COLOMBIA   RONDA CARIBE NUEVE   Exploration   Colombia   50%
PERENCO COLOMBIA LIMITED   San Jacinto y Rio Paez   Exploration   Colombia   36%
        Production   Colombia   18%
LEWIS ENERGY COLOMBIA INC   Clarinero   Exploration   Colombia   50%

 

F-65 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

  

34.Segment information

 

34.1Basis of classification

 

The Group operates under three segments: 1) Exploration and Production, 2) Transportation and Logistics and 3) Refining, petrochemicals and biofuels.

 

1)Exploration and Production - this segment includes the Company’s oil and gas exploration and production activities. Revenue is derived from the sale of crude oil, regulated fuels, unregulated fuels and natural gas to inter-company segments, at market prices, and to third parties (local and foreign distributors). Costs include those costs incurred in production. Expenses include all exploration costs that are not capitalized.

 

2)Transportation and Logistics - this segment includes the Company’s sales and costs associated with the transportation and distributors of crude oil, motor fuels, fuel oil and other refined products.

 

3)Refining and Petrochemicals - this segment includes the Company’s refining activities performed in the Barrancabermeja and Cartagena refineries, where crude oil from locations is transformed into products. Revenue is derived from the sale of goods sold, both locally and to third parties (local and foreign), including refined products such as motor fuels, fuel oils and petrochemicals at market prices, as well as some regulated fuels. This segment also includes sales of industrial services to third parties.

 

These functions have been defined as the operating segments of the Group since these are the segments (a) that engage in business activities from which revenues are earned and expenses are incurred; (b) whose operating results are regularly reviewed by the Group’s chief operating decision maker to allocate resources to the segments and assess their performance; and (c) for which discrete financial information is available. Internal transfers represent sales to intercompany segments and are recorded and presented at market prices.

 

34.2Financial information by segments

 

The following segment information is reported based on the information used by the Board, as the top body to make strategic and operational decisions of these business segments. The performance of the segments are based primarily on an analysis of income, costs, expenses and results for the period generated by each segment , which are regularly monitored.

 

The information disclosed in each segment is presented net of transactions between the Group companies.

 

The following presents the consolidated statement of profit and loss and other comprehensive income for the years ended December 31, 2015 and 2014:

 

F-66 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

   For the year ended December 31, 2015 
  

Exploration and

production

   Refining and
petrochemicals
   Transportation
and logistics
   Eliminations   Total 
Third-party sales   25,669,213    22,456,866    4,221,192    -    52,347,271 
Inter-segment sales   6,063,398    788,810    6,623,358    (13,475,566)   - 
Total Revenue   31,732,611    23,245,676    10,844,550    (13,475,566)   52,347,271 
Fixed costs   7,208,632    1,902,797    3,304,815    (2,790,793)   9,625,451 
Variable costs   18,500,240    18,856,011    439,607    (10,426,793)   27,369,065 
Cost of sales   25,708,872    20,758,808    3,744,422    (13,217,586)   36,994,516 
Gross income   6,023,739    2,486,868    7,100,128    (257,980)   15,352,755 
Administration expenses   731,626    451,250    518,109    -    1,700,985 
Operation and projects expenses   2,969,723    1,155,301    157,596    (248,352)   4,034,268 
Impairment of non-current assets   4,504,497    3,278,993    81,388         7,864,878 
Other operating income and expenses, net   (399,954)   122,595    (101,182)   -    (378,541)
Operating income   (1,782,153)   (2,521,271)   6,444,217    (9,628)   2,131,165 
Finance results, net                         
Financial income   536,121    135,622    86,568    (136,387)   621,924 
Financial expenses   (1,774,090)   (451,906)   (492,485)   67    (2,718,414)
Foreign exchange gain (loss), net   (4,798,741)   (949,176)   181,303    -    (5,566,614)
    (6,036,710)   (1,265,460)   (224,614)   (136,320)   (7,663,104)
Share of profit of companies   (70,407)   23,187    533    -    (46,687)
Income before tax   (7,889,270)   (3,763,544)   6,220,136    (145,948)   (5,578,626)
Income tax   2,037,650    (257,256)   (2,490,747)   -    (710,353)
Net income (loss)  for the period   (5,851,620)   (4,020,800)   3,729,389    (145,948)   (6,288,979)
Income attributable to:                         
Owners of the Company   (5,851,620)   (4,016,050)   2,819,759    (145,948)   (7,193,859)
Non-controlling interests   -    (4,750)   909,630    -    904,880 
    (5,851,620)   (4,020,800)   3,729,389    (145,948)   (6,288,979)
                          
Supplementary information                         
Depreciation, depletion and amortization   5,318,587    570,033    881,738    -    6,770,358 

 

   For the year ended December 31, 2014 
  

Exploration and

production

   Refining and
petrochemicals
   Transportation
and logistics
   Eliminations   Total 
Third-party sales   35,903,045    26,612,204    3,456,639    -    65,971,888 
Inter-segment sales   9,252,146    560,096    4,887,295    (14,699,537)   - 
Total Revenue   45,155,191    27,172,300    8,343,934    (14,699,537)   65,971,888 
Fixed costs   6,788,549    1,888,558    3,538,797    (1,981,744)   10,234,160 
Variable costs   21,139,234    23,648,670    402,255    (12,449,191)   32,740,968 
Cost of sales   27,927,783    25,537,228    3,941,052    (14,430,935)   42,975,128 
Gross income   17,227,408    1,635,072    4,402,882    (268,602)   22,996,760 
Administration expenses   335,432    354,221    341,523    (141)   1,031,035 
Operation and projects expenses   4,288,108    1,039,695    380,940    (188,418)   5,520,325 
Impairment of non-current assets   965,607    1,340,086    (1,121)   -    2,304,572 
Other operating income and expenses, net   (285,821)   12,490    (36,643)   1,775    (308,199)
Operating income   11,924,082    (1,111,420)   3,718,183    (81,818)   14,449,027 
Finance results, net                         
Financial income   251,902    113,237    127,262    (92,583)   399,818 
Financial expenses   (837,510)   (306,174)   (496,615)   5    (1,640,294)
Foreign exchange gain (loss), net   (2,243,938)   (309,449)   283,194    -    (2,270,193)
    (2,829,546)   (502,386)   (86,159)   (92,578)   (3,510,669)
Share of profit of companies   154,816    11,254    -    -    166,070 
Income before tax   9,249,352    (1,602,552)   3,632,024    (174,396)   11,104,428 
Income tax   (4,159,511)   (29,251)   (1,246,093)   -    (5,434,855)
Net income for the period   5,089,841    (1,631,803)   2,385,931    (174,396)   5,669,573 
Income attributable to:                         
Owners of the Company   5,089,841    (1,627,705)   1,758,777    (174,396)   5,046,517 
Non-controlling interests   -    (4,098)   627,154    -    623,056 
    5,089,841    (1,631,803)   2,385,931    (174,396)   5,669,573 
                          
Supplementary information                         
Depreciation, depletion and amortization   5,172,743    548,539    695,925    -    6,417,207 

 

F-67 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

34.3Sales of products by segment, geographic areas, customers and investments

 

The following is the detail of sales of products by segment for the years ended December 31, 2015 and 2014:

 

   Exploration and
production
   Refining and
petrochemicals
   Transportation
and logistics
   Eliminations   Total 
Local sales                         
Med-distillates   25,782    10,206,599    -    (17,157)   10,215,224 
Gasoline   -    6,464,661    -    (336,453)   6,128,208 
Services   118,812    198,369    10,822,078    (6,703,985)   4,435,274 
Natural gas   2,198,284    -    -    (352,939)   1,845,345 
Crude oil   5,847,368    -    -    (5,356,089)   491,279 
Diesel and asphalts   49,583    411,605    -    -    461,188 
Plastic and rubber   -    724,392    -    -    724,392 
L.P.G. and propane   154,201    190,346    -    (9,053)   335,494 
Other products   262,906    1,070,725    22,472    (367,757)   988,346 
    8,656,936    19,266,697    10,844,550    (13,143,433)   25,624,750 
Recognition of price  differential   -    441,871    -    -    441,871 
    8,656,936    19,708,568    10,844,550    (13,143,433)   26,066,621 
Foreign sales                         
Crude   21,495,762    -    -    (314,497)   21,181,265 
Fuel oil   -    2,166,469    -    -    2,166,469 
Trading of crude   1,309,196                   1,309,196 
Natural gas   233,500    -    -    (50,550)   182,950 
Gasoline and turbo fuel   27,756    65,369    -    -    93,125 
Diesel   -    81,982    -    -    81,982 
Plastic and rubber   -    1,096,730    -    -    1,096,730 
Cash flow hedging –  Reclassification to profit or loss   7,646    -    -    -    7,646 
Other products and services   1,815    126,558    -    32,914    161,287 
    23,075,675    3,537,108    -    (332,133)   26,280,650 
Total revenue   31,732,611    23,245,676    10,844,550    (13,475,566)   52,347,271 

 

F-68 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

 

   Exploration
and production
   Refining and
petrochemicals
   Transportation and
logistics
   Eliminations   Total 
Local sales                         
Med-distillates   1,241    11,982,214    -    -    11,983,455 
Gasoline   -    6,979,197    -    (584,775)   6,394,422 
Services   245,798    152,267    8,324,753    (4,944,745)   3,778,073 
Natural gas   1,580,941    -    -    (234,316)   1,346,625 
Crude oil   9,487,864    -    -    (8,274,146)   1,213,718 
Diesel and asphalts   46,336    412,736    -    -    459,072 
Plastic and rubber   -    667,563    -    -    667,563 
L.P.G. and propane   181,806    248,578    -    (3,934)   426,450 
Other products   102,696    812,510    19,181    66,934    1,001,321 
    11,646,682    21,255,065    8,343,934    (13,974,982)   27,270,699 
Recognition of price  differential        485,409    -    -    485,409 
    11,646,682    21,740,474    8,343,934    (13,974,982)   27,756,108 
Foreign sales                         
Crude   31,524,915    -    -    (689,405)   30,835,510 
Fuel oil   -    3,921,703    -    -    3,921,703 
Trading of crude   1,486,060                   1,486,060 
Natural gas   439,076    -    -    (15,615)   423,461 
Gasoline and turbo fuel   -    127,090    -    -    127,090 
Diesel   -    179,738    -    -    179,738 
Plastic and rubber   -    975,282    -    -    975,282 
Other products and services   58,458    228,013    -    (19,535)   266,936 
    33,508,509    5,431,826    -    (724,555)   38,215,780 
Total revenue   45,155,191    27,172,300    8,343,934    (14,699,537)   65,971,888 

 

Sales by geographic areas

 

Operating revenue by geographic areas is comprised as follows:

 

Zona  2015   Participation   2014   Participation 
Colombia   26,066,621    49.8%   27,756,108    42.1%
United States of America   11,921,720    22.8%   14,977,109    22.7%
Asia   6,123,593    11.7%   13,416,506    20.3%
Europe   3,981,926    7.6%   5,915,190    9.0%
Central America and Caribbean   3,366,978    6.4%   3,049,688    4.6%
South America and Others   886,433    1.7%   857,287    1.3%
Total   52,347,271    100.0%   65,971,888    100.0%

 

Concentration of customers

 

For the year ended December 31, 2015 one customer of the refining segment accounted 14.4% (2014 – 13.7%) of total sales. No other customers accounted more than 10% of total sales. There was no exposure that affects the financial position of Ecopetrol if the company lost the client.

 

Non-current assets distribution by geographic area

 

The majority of the Company’s assets and activities are located in Colombia. The financial position and results of operations of those subsidiaries located outside of Colombia are not material to the Group.

 

F-69 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

34.4Capital expenditures by Segment

 

The following table shows a breakdown of the changes of capital expenditures for years ended December 31, 2015 and 2014:

 

 

2015  Exploration and
production
   Refining and
petrochemicals
   Transportation and
logistics
  

Total

 

 
Property, plant and Equipment   2,460,975    3,590,279    2,497,679    8,548,933 
Natural and environmental resources   5,590,321    -    -    5,590,321 
Intangibles   69,126    18,494    24,635    112,255 
    8,120,422    3,608,773    2,522,314    14,251,509 

 

2014  Exploration and
production
   Refining and
petrochemicals
   Transportation and logistics   Total 
Property, plant and Equipment   3,556,536    3,730,289    1,636,743    8,923,568 
Natural and environmental resources   5,038,296    -    -    5,038,296 
Intangibles   26,610    10,636    74,772    112,018 
    8,621,442    3,740,925    1,711,515    14,073,882 

 

35.First-time adoption of International Financial Reporting Standards - IFRS

  

As part of the implementation process of International Financial Reporting Standards (hereinafter ¨IFRS¨) in conformity with the provisions of Act 1314 of 2009, Regulatory Decree 2784 of December 2012, Decrees 3023 and 3024 of 2013 and Decrees 2420 and 2496 of 2015 in Colombia, Ecopetrol S.A. and its subsidiaries belongs to Group 1 of preparers of financial information and therefore, these represent the first financial statements issued under International Financial Reporting Standards (at December 31, 2015 and an opening balance sheet at January 1, 2014, with 2014 being the transition period). The accounting policies set out in note 4 have been applied consistently since the opening balance sheet.

 

In preparing these financial statements, the Company has adjusted the figures previously reported in prior financial statements prepared in accordance with generally accepted accounting principles (previous GAAP), applying the following optional and mandatory exemptions for the retrospective application of IFRS.

 

35.1Exemptions to the retrospective application chosen by the company

  

(a)Business combinations – IFRS 1 includes an optional exception for business combinations as an alternative to applying IFRS 3 retrospectively (business combinations that occurred before the date of transition to IFRS). However, the entity may choose restating business combinations from any date prior to the date of transition. If any business combination is restated, then all later business combinations must also be restated and IFRS 10 is also applicable.

 

Ecopetrol applied the exemption set out above for all business combinations that occurred up to the date of transition. Therefore, it has not restated any business combination that took place before January 1, 2014, which were recorded at cost attributed in the opening statement.

 

(b)Fair value used as deemed cost of property, plant and equipment – The exemption to IFRS 1 allows fair value, at the date of the transition to IFRS, to be used as deemed cost of property, plant and equipment, intangible assets and investment properties. IFRS 1 establishes that a revaluation under previous GAAP (RCP), at the date of transition or prior, may be used as deemed cost, at the date of the revaluation, if it is broadly comparable to:

 

§Fair value; or
§Depreciated cost under IFRS.

 

Ecopetrol chose to measure certain land properties at fair value as at the transition date and use such amount as its deemed cost in the opening IFRS statement of financial position. Fair value was measured on the basis of a valuation performed by external, independent experts. For other Property, plant and equipment items, useful lives were established according to appraisals and technical support from the Company’s operating areas. Accumulated depreciation was recalculated based on these new useful lives and adjustments were recognized in the opening IFRS statement of financial position. For minor property, plant and equipment items such as office equipment, computer equipment and vehicles, the Company has considered depreciated or revaluated cost under RCP as deemed cost at the transition date, since it is comparable to its depreciated cost in accordance with IFRS.

 

(c)Leases – The exemption on IFRS 1 establishes that a company may determine whether arrangements in force on the date of the transition to IFRS are leases on the basis of the facts and circumstances existing at the date of transition.

 

F-70 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

Ecopetrol chose to apply this exemption and therefore has considered the facts and circumstances existing at the date of transition to determine the existence of implied leases in its contracts and agreements.

 

(d)Decommissioning liabilities included in the cost of property, plant and equipment – A first-time adopter may choose not to comply with requirements of IFRIC 1 for changes in decommissioning, restoration and similar liabilities. Therefore the Company can:

 

i.Measure the liability as at the date of transition in accordance with IAS 37;

 

ii.To the extent that the liability is within the scope of IFRIC 1, estimate the amount that would have been included in the cost of a related asset when the liability arose, by discounting the liability to that date using its best estimation of the historical risk-adjusted discount rate that would have applied for that liability over the corresponding period and;

 

iii.Calculate the accumulated depreciation on that amount, as at the date of transition to IFRS, on the basis of the current estimation of the useful life of the asset, using the depreciation policy adopted by the entity under IFRS.

 

Ecopetrol decided to apply this exemption and to measure, at the transition date, the asset retirement obligation and for the corresponding asset, to estimate the initial cost thereof and depreciate it on the transition date.

 

(e)Borrowing costs – IFRS 1 allows an entity to either capitalize borrowing costs incurred related to the construction of any qualifying assets; or designate a date before the date of transition and apply the standard to borrowing costs related to qualifying assets for which the commencement date for capitalization is on or after that designated date.

The Company chose to apply such exemption and adopted as a policy to capitalize borrowing costs under IAS 23 starting on the transition date.

 

(f)Classification of financial instruments – IFRS 1 includes a number of optional exemptions for first-time adopters, applying IFRS 9, in relation to the designation of previously recognized financial instruments. Ecopetrol chose to apply the following exemptions:

 

a.A first-time adopter may designate a financial asset as measured at a fair value through profit or loss provided that the asset meets the criteria for such classification as at the date of transition to IFRS.

 

b.An entity may designate an equity instrument as measured at a fair value through other comprehensive income provided that the asset meets the criteria for such classification as at the date of transition to IFRS.

 

(g)Fair value measurement of financial assets or financial liabilities at initial recognition – Ecopetrol applied measurement of financial assets and liabilities at fair value prospectively at the date of transition.

 

(h)Financial assets and intangible assets from service concession arrangements – Ecopetrol recognized financial assets and intangible assets at carrying amounts at the date of transition to IFRS.

 

(i)Effects of Changes in Foreign Exchange Rates – IFRS 1 allows the entity to not determine the cumulative translation differences recognized in other comprehensive income that existed at the date of transition to IFRS. If this exemption is applied, the cumulative translation differences for all foreign operations are deemed to be zero at the date of transition to IFRS.

 

35.2Reconciliation of financial position

 

The following reconciliations reflect the impact of the transition to IFRS on the financial position previously reported by Ecopetrol:

 

Equity reconciliation at December 31 and January 1, 2014:

 

      December 31,   January 1, 
   Note  2014   2014 
Consolidated shareholders’ equity under previous GAAP      68,545,972    71,119,203 
Property, plant and equipment and natural resources  (1)   (26,832,400)   (21,964,970)
Non-controlling interest in Equion  (2)   (1,017,201    (1,222,118)
Deferred tax  (3)   438,157    (194,681)
Deferred charges  (4)   (206,292)   (717,582)
Non-controlling interests  (5)   4,195,935    4,573,748 
Foreign currency translation  (6)   1,990,252    - 
Equity method and Investments in associates and joint ventures  (7)   760,965    (378,344)
Liabilities and assets at amortized cost, and others  (8)   612,271    38,882 
Employee benefits liability  (9)   46,569    (1,389,569)
Consolidated equity under IFRS      48,534,228    49,864,569 

 

F-71 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

(1)The detail of adjustments related to property, plant and equipment and natural resources, is as follows:

 

      December 31,   January 1, 
   Note  2014   2014 
Reversal of revaluation and provisions recognized under previous GAAP  (i)   (21,589,810)   (22,488,754)
Non-capitalized borrowing costs, and others  (ii)   (3,544,809)   (610,087)
Assets impairment  (iii)   (2,589,823)   (553,506)
Asset retirement obligation  (iv)   (594,501)   (679,238)
Depreciation and elimination of inflation adjustments  (v)   1,486,543    2,366,615 
Total property, plant and  equipment adjustments      (26,832,400)   (21,964,970)

 

i.Reversal of revaluations and provisions recognized under previous GAAP were made since the Company chose recognizing its property, plant and equipment, other than lands, at their cost.

 

ii.It mainly includes:

 

·Non-capitalized borrowing costs under IFRS in the amount of COP$3,201,531 in Ecopetrol S.A. and Reficar. Due to the exemption adopted by the Company which is described in Note 35.1 there is no value for this adjustment at the opening statement of financial position. Under previous GAAP, the Company capitalized a higher value of expense for exchange differences related to capital expenditures in foreign currency, while under IFRS the exchange difference is limited to a hypothetical debt expense in the functional currency of the company.

 

·Sales of oil production for assets under extensive tests in exploration and evaluation phase are recorded as a lower value of assets under IFRS of COP$157,420 (January 1, 2014 - COP$146,985). Under previous GAAP these sales were recognized as income.

 

·Adjustment for assets related to incorporated institutional equity in the amount of COP$41,203 (January 1, 2014 – COP$43,033)

 

·Effect generated by the analysis of the recognition criteria of assets under IFRS and others minor adjustments of COP$582,122 (January 1, 2014 - COP$636,369).

 

·The factors mentioned above were partially offset by adjustment of COP$438,188 for capitalized maintenance (January 1, 2014 – COP$216,302).

 

iii.Recognition of the asset impairment loss, pursuant to the criteria established under IAS 36 – Impairment of assets, taking into account that the Company determined as Cash Generating Units –CGU the oil and gas producing fields, the refineries and the pipelines or poliducts. This differs from the previous GAAP, which only recognized obsolescence loss.

 

iv.Effect for recognition, at present value, of the dismantlement and asset retirement costs and their associated depreciation. Under the previous GAAP, this obligation was recognized at face value and it was estimated mainly for Exploration and Production assets. Under IFRS, the Company recognized an asset retirement obligation for its Transport and Logistics assets.

 

v.Effect generated by the change in useful lives and depreciation method of assets. Under previous GAAP useful lives of property, plant and equipment were established under tax criteria. Under IFRS useful lives are established based on technical and economic criteria. In addition, we eliminated the inflation adjustments due to they are not allowed under IFRS; therefore, the company uses the cost method under IFRS.

 

F-72 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

(2)As a result of the evaluation of control over companies, it was determined under IFRS that Equion will be recognized as a joint venture valued by the equity method. Under the previous GAAP, the Company consolidated this investment.

 

(3)Variation in deferred tax generated by measurement of assets and liabilities under IFRS. Main variations are: increase in carrying amount of property, plant and equipment generating a higher deferred tax liability, presumptive income tax excesses and tax loss carry forwards generating a higher deferred tax asset. Under previous GAAP, deferred taxes were not calculated on these concepts.

 

(4)A decrease is presented in deferred charges due to that under IFRS certain items, such as tax on equity, do not meet the criteria for recognition as assets.

 

(5)Under IFRS, non-controlling interest should be presented as part of the equity. Under previous GAAP, non-controlling interest were presented as a higher value of liabilities.

 

(6)It corresponds to the adjustments in foreign currency translation, for consolidation purposes, of those companies under the Ecopetrol Business Group with a functional currency different to the Colombian peso. Under previous GAAP, all Companies in Colombia had the Colombian peso as their functional currency, but for IFRS, some of them adopted US dollar as their functional currency.

 

(7)Recalculation in the equity method for investments made in associates and joint ventures amounting. This adjustment is generated after the recognition of Equion as a joint venture and the change of the accounting bases of the associates and joint ventures under IFRS (including goodwill adjustments).

 

(8)It includes the following adjustments:

 

·With the adoption of IFRS, loans are valued using the amortized cost methodology, using the effective interest rate. Under previous GAAP, loans were recognized at their face value, registering the respective interest. The effect amounts to COP$736,515 (January 1, 2014, COP$38,257).

 

·Other minor adjustments for the amount of COP$(124,244) (January 1, 2014 - COP$625).

 

(9)With the adoption of IFRS, the assets that support the pension liability (pension-related autonomous equities – PAP, by its acronym in Spanish) are part of the statement of financial position as well as the liabilities corresponding to labor obligations subject to actuarial estimation (pensions, pension bonds, five-year period bonus, healthcare and education). Such estimation is made under IFRS guidelines using the projected unit credit method, which differ from estimations performed under previous GAAP, mainly in the rate used in the actuarial calculations (under IFRS corresponds to a long-term rate, while under previous GAAP, this rate is fixed by law).

 

35.3Reconciliation of net income

 

Reconciliation of net income for the year ended December 31, 2014:

 

      2014 
Consolidated net income under previous GAAP      8,285,679 
Foreign currency exchange and borrowing cost  (a)   (3,201,531)
Property, plant and equipment, and natural resources  (b)   (2,564,842)
Deferred charges  (c)   511,290 
Labor liability  (d)   427,241 
Deferred taxes  (e)   632,838 
Consolidation, inventories, equity method and others  (f)   1,731,251 
Non-controlling interest  (g)   (152,353)
Consolidated net income under IFRS      5,669,573 
Accumulated foreign currency translation   (h)   3,398,374 
Net fair value gain  on available-for-sale financial assets  (i)   76,435 
Update of defined benefit obligation  (d)   743,793 
Total comprehensive income under IFRS      9,888,175 

 

(a)Net income under IFRS decreased as a result of the exchange difference on foreign currency loans and interest on loans, which under previous GAAP were recorded as value of investment projects, without limitation. Under IFRS, the exchange difference on foreign currency loans and related interest are limited to costs incurred on a hypothetical scenario of debt in the functional currency of the Company.

 

F-73 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

(b)Adjustments made to the property, plant and equipment and natural resources are given by: i) a lower depreciable base that generates a lower depreciation expense due to the use of useful lives that consider the expected use of the asset and their estimated cost of dismantling and removing, which are discounted to the present value. Under previous GAAP, the useful lives used correspond to higher useful lives used for tax purposes and the costs of dismantling were not discounted to the present value; ii) higher impairment expense generated by different accounting bases in the annual evaluation of the recoverable amount of the Cash Generating Units.

 

(c)Adjustments generated mainly due to the reversal for IFRS spending generated equity tax, which, for the opening statement of financial position, was completely recognized. According to previous GAAP, Equity tax was recorded gradually in the statement of income for a 4-year period (2010-2014).

 

(d)There is an increase in net income under IFRS because actuarial gains or losses regarding pension assets and liabilities for retired employees are recognized directly in equity, in other comprehensive income. Under previous GAAP, these updates were carried directly as a result for the financial year. In addition, under IFRS, a financial cost component is recognized in respect of labor liabilities subject to actuarial calculation, with an impact on the results for the financial year. Under previous GAAP, the monetary correction component is not recognized.

 

(e)Differences in deferred taxes under IFRS and previous GAAP are generated due to variations in the measurement of assets and liabilities applying IFRS, which have resulted in temporary differences in assets (liabilities), among which are: a) a higher value of deferred tax assets caused by change in the accounting methodology in capitalized interest and exchange difference, b) changes in the accounting basis of property, plant and equipment, which were caused by the first-time IFRS adoption, which generates a lower depreciation, c) difference in the Asset Retirement Obligation compared to previous GAAP that generate higher deferred tax expense.

 

(f)Consolidation adjustments for differences between IFRS and previous GAAP, mainly in unrealized profits and application of the equity method in associates and non-controlling interest recalculation effects.

 

(g)Non-controlling interest recalculation effects under IFRS.

 

(h)It corresponds to the foreign currency translation, for consolidation purposes, of those companies under the Ecopetrol Business Group with a functional currency different to the Colombian peso.

 

(i)The gain in the valuation of assets held for sale relates to the fair-value recognition of the equity interest held by Ecopetrol S.A. in Interconexión Eléctrica S.A and Empresa de Energía de Bogotá, where under IFRS, gains and losses arising from the measurement of these assets' fair value are recorded in Other comprehensive income. Under previous GAAP, these investments were measured at historical cost.

 

35.4Reconciliation of cash flow

 

At December 31, 2014, cash and cash equivalents under previous GAAP amounted COP$7,951,201 and under IFRS amounted to COP$7,618,178. The difference between IFRS and previous GAAP of COP$333,023 is explained by:

 

a)An increase of COP$131,388 due to changes in the presentation criteria of financial resources, which under the previous accounting principles were recognized as other financial assets.

 

b)A decrease of COP$464,411 in cash due to the non-consolidation of Equion Energy Limited.

 

The transition from Colombian GAAP to IFRS did not materially change the underlying cash flows of the Company.

 

The main changes in operating activities are justified by the impact explained in section 35.3 and reclassifications of financial interest paid and receipts, which for previous GAAP regulations were recorded under operating cash flows. The change in investment activities is generated by the presentation of interest received under investing activities and the difference in the criteria for capitalization of maintenance of fixed assets; and the change in financing activities is for the presentation of interest paid under financing activities which were presented within operating activities under previous GAAP.

 

F-74 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

36.Subsequent events

 

-On January 28, 2016, Ecopetrol's Board of Directors approved commencement of the process for sale of its shareholding in the company Polipropileno del Caribe S.A. – Propilco S.A., in order to obtain funds to strengthen the Exploration and Production business. This process means that Ecopetrol S.A. must apply for and obtain the relevant approval from the National Government.

 

-In January 2016, Ecopetrol acquired a bilateral commercial loan in the amount of USD 175 million (equivalent to COP$578 billion). The transaction was performed with The Bank of Tokyo-Mitsubushi UFJ, Ltd. comprising a 5-year term, repayable with a 2.5 year grace period on the principal and with interest payable semiannually at the Libor rate + 145 basis points. Also, in February 2016, the company acquired a commercial loan in national currency with Bancolombia S.A. in the amount of COP$990,000, over an 8-year term, repayable with a 2 year grace period on the principal, and interest at the DTF rate (Colombia's benchmark 90-day time deposit rate) + 560 basis points, payable semiannually.

 

-The Board of Directors of Ecopetrol made the decision to withdraw the company's ADRs from the Toronto Stock Exchange. This decision is based on the analysis performed by the Board (and others), the low volume of ADRs traded in Canada, and the existence of a liquid market for the ADRs on the New York Stock Exchange, and for ordinary shares in the Colombian domestic market on the Colombian Stock Exchange (Bolsa de Valores de Colombia in Spanish).

 

-Ecopetrol decided to suspend production and development activities in the Caño Sur Este field, located in Puerto Gaitán (Meta), south of the Rubiales field, because despite the efficiencies applied, the field is not able to achieve profitability in the current context

 

-Between 2008 and 2015 Refineria de Cartagena S.A. undertook a process to modernize its refinery. As of the close of December 2015, the refinery plant represents an approximate cost of USD 7,610. In January, 2016 the Comptroller General of the Republic issued a report called "Refineria de Cartagena: Lessons learned and not learned for a megaproject," which does not contain any administrative, tax, criminal or disciplinary findings. The Comptroller General of the Republic initiated Special Action in order to evaluate Reficar's management of the modernization and expansion of the Cartagena refinery, in order to determine whether public funds were managed properly, based on an analysis of Reficar's institutional and financial model. To date, this action is in progress. In turn, the Attorney General's Office has announced the start of investigation, and the State Prosecutor General's Office, in addition to the investigation it has been conducting since 2012, has announced another, within the scope of its respective functions. Ecopetrol and Reficar have provided the information requested and continue to provide support to all control bodies for review of the facts pertaining to these inquiries.

 

Meanwhile, Ecopetrol S.A. and Refineria de Cartagena S.A. (its subsidiary) have enabled the protocol for evaluation and review of the matters raised by the Comptroller General of the Republic, among others. On March 8, 2016, Refinería de Cartagena S.A. filed a Request for Arbitration with the International Chamber of Commerce (the“ICC”) against Chicago Bridge & Iron Company N.V., CB&I (UK) Limited, and CBI Colombiana S.A. (collectively, “CB&I”) with respect to the Engineering, Procurement, and Construction Contract (the “EPC Contract”) entered into by and between Reficar and CB&I for the expansion of the Cartagena refinery in Cartagena, Colombia.  Reficar is the Claimant in the ICC arbitration proceeding and seeks no less than USD 2,000 million from CB&I.  

 

-Board of Directors approved a 2016-2020 road map for the Barrancabermeja Refinery, with the objective of maximizing its long-term competitiveness and sustainability, as established in the Ecopetrol’ s strategic plan announced in May 2015. The crude oversupply in the international oil and gas markets has deteriorated oil prices. Under this environment, Ecopetrol, in line with industry trends, has focused on making its operations profitable by optimizing costs and implementing strict austerity measures, in addition to adjusting its investment plan, only approving projects that create the highest value and generate the most cash flows in the short-term.

 

In this challenging scenario, and in an effort to ensure the financial sustainability of the Ecopetrol group, Ecopetrol has decided that it is necessary to suspend the Barrancabermeja Refinery Modernization Plan (PMRB) until the oil price environment allows investments to be made in such a major project. 

 

-Through of the Colombian Stock Exchange (Bolsa de Valores de Colombia S.A.), the second auction was held for the second stage of the program to divest and sell 58,925,480 of Ecopetrol’s shares of the company Interconexion Electrica S.A. E.S.P. The amount of the transaction was COP$377,081.

 

F-75 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

Supplemental information on Oil and Gas producing activities (unaudited)

 

In accordance with the requirements of the United States Securities and Exchange Commission (SEC), Release 33-8879, Accounting Standards Codification 932 and the ASU- 2010-03 “Oil and Gas reserve Estimation and Disclosures” rule, this section provides supplemental information on oil and gas exploration and producing activities of the Company. The information included in sections 36.1 to 36.3 provides historical cost information pertaining to costs incurred in exploration, property acquisitions and development, capitalized costs and results of operations. The information included in sections d) and e) presents information on Ecopetrol’s estimated net proved reserve quantities, standardized measure of estimated discounted future net cash flows related to proved reserves, and changes in estimated discounted future net cash flows.

 

The following information corresponds to Ecopetrol’s oil and gas producing activities at December 31 2015, 2014 and January 1, 2014 in direct and joint operations.

 

Under the SEC final rule, optional disclosure of possible and probable reserves is allowed. But, the Company opted not to do so. Ecopetrol estimated its reserves without considering non-traditional resources.

 

a)Capitalized costs relating to oil and gas producing activities

 

   December 31,   January 1, 
   2015   2014   2014 
Natural and environmental properties   45,789,713    40,356,524    34,130,988 
Wells, equipment and facilities – property, plant and equipment   21,822,897    17,839,350    15,088,154 
Construction in progress   9,145,198    8,110,401    8,426,066 
Accumulated depreciation, depletion and amortization   (39,743,147)   (32,003,657)   (25,681,664)
Net capitalized costs   37,014,661    34,302,618    31,963,544 

 

It includes information of the exploration and production segment subsidiaries.

 

In accordance with IAS 37, these natural and environmental costs include the asset retirement obligations amounting COP$580,575, COP$1,061,392, and COP$579,611, during 2015, 2014 and January 1, 2014, respectively

 

b)Costs incurred in oil and gas exploration and developed activities

 

Costs incurred are summarized below and include both amounts expensed and capitalized in the corresponding period.

 

   Year ended December 31 
   2015   2014 
Acquisition of proved properties (1)   -    16,747 
Acquisition of unproved properties (2)   357,772    263,057 
Exploration costs   1,012,264    2,036,526 
Development costs   8,018,131    8,189,239 
Total costs incurred   9,388,167    10,505,569 

 

(1)Represents the scheduled buy-in costs paid to Murphy Oil (Operator) to participate in the Dalmatian and Gunflint projects.

 

(2)It relates to drilling for the Leon 2 exploratory project, operated by Repsol as well as acquisition of the Lease Sales 235 and 246 (unproven lands), in 2015. For 2014, it corresponds to drilling for the Ridberg/Aleatico and Leon 1 exploratory projects, operated by Shell and Repsol, respectively, as well as acquisition of the Lease Sale 231 (unproven lands).

 

F-76 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

c)Results of operations for oil and gas producing activities

 

   2015   2014 
Net revenues          
Sales   26,039,708    36,678,579 
Transfers   5,692,902    8,476,612 
Total   31,732,610    45,155,191 
           
Production cost (1)   6,006,563    6,457,013 
Depreciation, depletion and amortization (2)   9,887,331    6,129,538 
Other production costs (3)   14,457,836    16,406,789 
Exploration expenses (4)   1,586,940    2,590,778 
Other expenses (5)   2,711,274    2,478,563 
Total   34,649,943    34,062,681 
Income before income tax   (2,917,333)   11,092,510 
Income tax expenses   (371,376)   (5,428,674)
Results of operations for producing activities   (3,288,710)   5,663,836 

 

(1) Production costs are lifting costs incurred to operate and maintain productive wells and related equipment and facilities, including costs such as operating labor, materials, supplies, and fuel consumed in operations and the costs of operating natural gas liquids plants. In addition, it includes accretion expense related to the asset retirement obligations that were recognized during 2015 and 2014, amounting approximately COP$206,570 and COP$184,648, respectively. The Company’s results of operations from oil and gas producing activities for the years ending December 31, 2015 and 2014 are shown above.

 

(2) In accordance with IAS 37, the expense related to asset retirement obligations that were recognized during 2015 and 2014 in depreciation, depletion and amortization, amounted approximately to COP$294,849 and COP$160,106, respectively.

 

(3) Corresponds to transportation costs and naphtha that are not part of the Company´s lifting cost.

 

(4) Exploration expenses include the costs of geological and geophysical activities as well as the non-productive exploratory wells.

 

(5) Corresponds to administration and marketing expenses.

 

During 2015 and 2014, respectively, the Company transferred approximately 18% and 19% of its crude oil and gas production; (percentages based on the value sales in Colombian pesos) to intercompany business units. Base on volume, those transfers were 37% and 39%, respectively (including Reficar). The intercompany transfers were recorded at values equal to the Company’s market prices.

 

d)Reserve information

 

Ecopetrol follows international standards for estimating, classifying and reporting reserves, framed under SEC definitions. The process is led by the Reserves Department, which submits the report to the Board of Directors for approval.

 

The reserves were audited at a level of 99% by 2 specialized auditing companies: DeGolyer and MacNaughton, and Ryder Scott Company. According to these certifications, the reserves report complies with the content and guidelines set forth in Rule 4-10 of Regulation S-X issued by the United States SEC.

 

The following information relates to the net proven reserves owned by the Business group in 2015, 2014 and 2013, and corresponds to the official reserves statements prepared by the Company:

 

   2015   2014   2013 
   Oil   Gas   Total   Oil   Gas   Total   Oil   Gas   Total 
   million barrels   billion cf   million boe   million barrels   billion cf   Million boe   Million barrels   billion cf   million boe 
Proved Reserves:                                             
Beginning of year   1,465.2    3,529.0    2,084.3    1,433.6    3,068.4    1,971.9    1,370.3    2,886.4    1,876.7 
Revisions of previous estimates   (64.2)   224.8    (24.7)   153.7    665.1    270.4    172.7    337.5    231.9 
Improved recovery   15.3    2.9    15.8    34.0    0.4    34.1    23.2    19.9    26.7 
Purchases of minerals in place   -    -    -    -    -    -    7.5    11.0    9.4 
Extensions and discoveries   24.4    0.4    24.4    40.6    59.0    50.9    66.2    49.3    74.9 
Sales of minerals in place   -    -    -    -    -    -    (0.6    (12.3)   (2.8)
Production   (202.0)   (277.8)   (250.7)   (196.8)   (263.8)   (243.0)   (205.7)   (223.5)   (244.9 
End of year   1,238.8    3,479.2    1,849.2    1,465.2    3,529.0    2,084.3    1,433.6    3,068.4    1,971.9 
                                              
Proved developed reserves:                                             
Beginning of year   1,042.3    3,284.0    1,618.5    933.0    2,663.3    1,400.2    933.3    2,535.9    1,378.2 
End of year   912.8    3,176.0    1,470.0    1,042.3    3,284.0    1,618.5    933.0    2,663.3    1,400.3 
Proved undeveloped reserves:                                             
Beginning of year   422.9    244.9    465.9    500.6    405.0    571.7    437.0    350.6    498.5 
End of year   326.0    303.3    379.2    422.9    244.9    465.9    500.6    405.0    571.7 

 

F-77 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

The section Overview Business – Exploration and Production – Reserves contains additional information of the process of estimating reserves and main explanations about the changes in Proved Reserves.

 

e)Standardized measure of discounted future net cash flows relating to proved oil and gas quantities and changes therein

 

The standardized measure of discounted future net cash flows, related to the above proved crude oil and natural gas reserves, is calculated in accordance with the requirements of ASU 2010-03. Estimated future cash inflows from production under SEC requirements are computed by applying unweighted arithmetic average of the first-day-of-the-month for oil and gas price to year-end quantities of estimated net proved reserves.

 

   2015   2014 
Future cash inflows   176,865,586    310,138,127 
Future costs          
Production   (76,363,169)   (107,629,865)
Development   (16,498,118)   (23,504,455)
Income tax expenses   (30,052,830)   (60,366,272)
Future net cash flow   53,951,469    118,637,535 
10% annual discount for estimated timing of cash flows   (19,117,422)   (43,604,395)
Standardized measure of discounted future net cash flows   34,834,047    75,033,140 

 

The following are the principal sources of change in the standardized measure of discounted net cash flows: 

 

   2015   2014 
         
Net change in sales and transfer prices and in production (lifting) cost related to future production   (50,472,025)   12,924,167 
Changes in estimated future development costs   592,529    (10,987,031)
Sales and transfer of oil and gas produced during the period   (25,726,047)   (38,698,178)
Net change due to extensions and discoveries   (93,190)   (902,356)
Net change due to purchase and (sales) of minerals in place   -    - 
Net change due to revisions in quantity estimates   (985,217)   18,866,518 
Previously estimated development costs incurred during the period   10,769,369    8,702,964 
Accretion of discount   11,321,221    11,018,459 
Timing and other   (4,381,037)   2,103,078 
Net change in income taxes   18,775,304    (1,254,706)
Aggregate change in the Standardized measure of discounted future net cash flows for the year   (40,199,093)   1,772,915 

 

F-78 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

Exhibit 1 - Consolidated companies, associates and joint ventures

 

The following tables summarizes the information for subsidiaries, associates and Joint Ventures as of December 31, 2015

 

Consolidated subsidiaries

 

Company 

Ownership Interest

Ecopetrol

   Activity  Shared interest  Country/ Domicile  Geographic area of
operations
  Net Equity   Income (loss) for the
period
 
Ecopetrol Global Energy   100%   Investment vehicle.  Ecopetrol America Inc., Ecopetrol oleo & Gas do Brasil Ltda, Ecopetrol del Perú S. A., Ecopetrol Germany Gmbh, Refineria de Cartagena S. A.,Bioenergy S. A.  Spain  Spain   2,995,805    (1,693,311) 
Ecopetrol Oleo é Gas do Brasil Ltda.   100%   Hydrocarbon exploration and exploitation.  Sociedad portuaria de oleofinas y derivados, Propileno del Caribe S. A  Brazil  Brazil   23,489    (64,654) 
Ecopetrol del Perú S. A.   100%   Hydrocarbon exploration and exploitation.  Propileno del Caribe S.A  Peru  Peru   57,037    (28,177) 
Ecopetrol América Inc.   100%   Hydrocarbon exploration and exploitation.  Ecopetrol Perú S.A, Ecopetrol Oleo é Gas do Brasil Ltda. ,Propileno del Caribe S. A,Sociedad portuaria deoleofinas y derivados  United States of America  United States of America   2,895,667    (1,530,457) 
Black Gold Re Ltd.   100%   Reinsurer of Ecopetrol and its subsidiaries.  -  Bermuda  Bermuda   572,662    32,932) 
Ecopetrol Germany Gmbh   100%   Hydrocarbon exploration and exploitation.  -  Germany  Angola   19,506    (69,529) 
Hocol Petroleum Limited   100%   Investment vehicle.  Hocol S. A.  Bermuda  Bermuda   4,276,727    (240,467) 
Hocol S.A   100%   Hydrocarbon exploration, exploitation and production.  Oleoducto de Colombia S.A. y Oleoducto Bicentenario OBC  Cayman Islands  Colombia   2,238,221    (261,729) 
Andean Chemicals Ltd.   100%   Investment vehicle.  Bioenergy S. A., Refineria de Cartagena, Propileno del Caribe S. A, Comai S.A Sociedad Portuaria Olefinas y derivados.  Bermuda  Bermuda   5,964,361    (1,744,606) 
Refineria de Cartagena S. A.   100%   Hydrocarbons refining, marketing and distribution.  -  Colombia  Colombia   7,810,190    (4,234,388) 
Propileno del Caribe Propilco S. A.   100%   Production and marketing of polypropylene resin.  Comai S. A., Refineria de Cartagena., Bioenergy S. A. Sociedad Porturaria Olefinas y Derivados  Colombia  Colombia   1,202,652    103,851 
COMAI - Compounding and Masterbatching Industry   100%   Manufacturing of polypropylene compounds and master batches for a wide range of uses.  Refineria de Cartagena., Bioenergy S. A., Zona franca de cartagena S.A , Sociedad Portuaria del Dique  Colombia  Colombia   112,567    51,666 
Bioenergy S. A.   93.47%   Biofuels production.  Bioenergy Zona Franca S. A., Amandine Holdings Corp. y Los Arces Group Corp.  Colombia  Colombia   286,680    (108,422) 
Bioenergy Zona Franca S. A. S.   93.47%   Biofuels production.  -  Colombia  Colombia   259,080    (91,211) 
Amandine Holdings Corp.   93.47%   In a winding-up process.  -  Panama  Panama   6,657    - 
Los Arces Group Corp.   93.47%   In a winding-up process.  -  Panama  Panama   5,100    - 
Cenit S.A.S.   100%   Storage and transportation through hydrocarbon pipelines  Oleoducto Bicentenario, Ocensa, ODC, ODL, Serviport  Colombia  Colombia   11,584,811    3,110,127 
Oleoducto Central S. A. – Ocensa   72,65%   Pipeline transportation of crude oil.  -  Colombia  Colombia   2,768,287    1,954,128 
Oleoducto de los Llanos Orientales S. A. - ODL   65%   Pipeline transportation of crude oil.  -   Panamá  Colombia   1,202,479    303,710 
 Oleoducto de Colombia
S. A. – ODC
   73%   Pipeline transportation of crude oil.  -  Colombia  Colombia   378,739    243,996 
Oleoducto Bicentenario de Colombia SAS   55.97%   Pipeline transportation of crude oil.  -  Colombia  Colombia   938,158    334,798 
Ecopetrol Capital AG   100%   Financing, liquidation of funding for companies, groups or any business or related activity.  -  Switzerland  Switzerland   1,004,996    118,474 
Ecopetrol Global Capital S.L.U   100%   Investment vehicle.  -  Spain  Spain   87    (204) 

 

F-79 

Ecopetrol S. A.

Consolidated Financial Statements

For the years ended December 31, 2015 and 2014, at December 31, 2015 and 2014

and the opening statement of financial position at January 1, 2014.

(Expressed in millions of Colombian pesos)

 

Associates and joint ventures

 

Associates                     
Invercolsa S.A.   43,35%   Investment in companies of transport and distribution of Natural Gas and L.P.G. in Colombia  Colombia  Colombia   141,875    89,525 
Offshore International Group Inc.   50%   Hydrocarbon exploration, development, production and processing  United States of America  Peru   1,512,961    (237,564)
Serviport S.A.   49%   Services for oil-vessel loading and unloading support; supply of equipment for the same purpose; technical inspections and loading measurements  Colombia  Colombia   12,704    8,083 
Sociedad Portuaria Olefinas y Derivados S.A.   50%   Construction, use, maintenance, adaptation and administration of ports and private or public docks facilities  Colombia  Colombia   1,050    (202)

Joint ventures

                        
Equion Energía Limited   51%   Hydrocarbon exploration, exploitation and production  United Kingdom  Colombia   2,067,671    14,820 
Ecodiesel Colombia S.A.   50%   Hydrocarbon exploration, exploitation and production  Colombia  Colombia   74,322    26,989 

 

 F-80 

 

  

9.Signature Page

 

SIGNATURES

 

The registrant hereby certifies that it meets all of the requirements for filing on Form 20-F and that it has duly caused and authorized the undersigned to sign this annual report on its behalf.

 

  Ecopetrol S.A.
       
  By: /s/ María Fernanda Suárez
    Name: María Fernanda Suárez
    Title: Chief Financial Officer
       
  By: /s/ Juan Carlos Echeverry
    Name: Juan Carlos Echeverry
    Title: Chief Executive Officer

 

Dated: April 28, 2016

 

 151 

 

 

10.Exhibits

 

Exhibit No.   Description
     
1.1   Amended and Restated Bylaws of Ecopetrol S.A., dated March 26, 2015, as recorded under Public Deed No. 1049 of May 19, 2015 (incorporated by reference to Exhibit 3.1 on Form 6-K of the Company, furnished to the U.S. Securities and Exchange Commission on November 27, 2015 (File No. 001-34175)) (English Translation).
     
4.1   Transportation Agreement between Ecopetrol S.A. and Oleoducto Central S.A., dated March 31, 1995 (incorporated by reference to Exhibit 4.1 on Form 20-F filed with the U.S. Securities and Exchange Commission on September 12, 2008 (File No. 001-34175)) (English Translation).
     
4.2   Supplementary Agreement to Transportation Agreement between Ecopetrol S.A. and Oleoducto Central S.A., dated January 17, 2013 (incorporated by reference to Exhibit 4.2 on Form 20-F filed with the U.S. Securities and Exchange Commission on April 29, 2013 (File No. 001-34175)) (English Translation).
     
4.3   Natural Gas Transportation Agreement between Ecopetrol S.A. and Transportadora de Gas del Interior S.A. ESP, dated October 1, 2008 (incorporated by reference to Exhibit 4.3 on Form 20-F filed with the U.S. Securities and Exchange Commission on April 29, 2013 (File No. 001-34175)) (English Translation).
     
4.4   Supplementary Agreement No. 1, dated December 5, 2008, to the Natural Gas Transportation Agreement between Ecopetrol S.A. and Transportadora de Gas del Interior S.A. ESP, dated October 1, 2008 (incorporated by reference to Exhibit 4.4 on Form 20-F filed with the U.S. Securities and Exchange Commission on April 29, 2013 (File No. 001-34175)) (English Translation).
     
4.5   Supplementary Agreement No. 2, dated April 11, 2012, to the Natural Gas Transportation Agreement between Ecopetrol S.A. and Transportadora de Gas Internacional S.A. E.S.P., dated October 1, 2008 (incorporated by reference to Exhibit 4.5 on Form 20-F filed with the U.S. Securities and Exchange Commission on April 29, 2013 (File No. 001-34175)) (English Translation).
     
4.6   Crude Oil Transportation Services Agreement between Ecopetrol S.A. and Cenit Transporte y Logística de Hidrocarburos S.A.S., dated April 1, 2013 (incorporated by reference to Exhibit 4.6 on Form 20-F filed with the U.S. Securities and Exchange Commission on April 29, 2013 (File No. 001-34175)) (English Translation).
     
4.7   Refined Products Transportation Services Agreement between Ecopetrol S.A. and Cenit Transporte y Logística de Hidrocarburos S.A.S., dated April 1, 2013 (incorporated by reference to Exhibit 4.7 on Form 20-F filed with the U.S. Securities and Exchange Commission on April 29, 2013 (File No. 001-34175)) (English Translation).
     
4.8   Indenture, dated as of July 23, 2009, between the Company and The Bank of New York Mellon, as trustee (incorporated by reference to Exhibit 4.2 to the Company’s Form F-4 filed with the U.S. Securities and Exchange Commission on July 31, 2009 (File No. 333-160965)).
     
4.9   Bicentenario Transport Contract between Oleoducto Bicentenario de Colombia S.A.S. and Ecopetrol S.A., dated June 20, 2012 incorporated by reference to Exhibit 4.9 on Form 20-F filed with the U.S. Securities and Exchange Commission on April 25, 2014 (File No. 001-34175)) (English Translation).
     
4.10   Amendment No. 1 to the Indenture, dated as of June 26, 2015, between the Company and The Bank of New York Mellon, as trustee (incorporated by reference to Exhibit 4.10 on Form 6-K of the Company furnished to the U.S. Securities and Exchange Commission on June 25, 2015 (File No. 001-34175)).

 

 152 

 

 

Exhibit No.   Description
     
4.11   Supplementary Agreement No. 2, dated March 28, 2014, to the Bicentenario Transport Contract between Oleoducto Bicentenario de Colombia S.A.S. and Ecopetrol S.A., dated June 20, 2012 (English Translation).
     
4.12   Supplementary Agreement No. 4, dated April 6, 2015, to the Bicentenario Transport Contract between Oleoducto Bicentenario de Colombia S.A.S. and Ecopetrol S.A., dated June 20, 2012 (English Translation).
     
8.1   List of subsidiaries of Ecopetrol S.A.
     
12.1   Section 302 Certification of the Chief Executive Officer.
     
12.2   Section 302 Certification of the Chief Financial Officer.
     
13.1   Section 906 Officer Certification.
     
15.1   Consent letter of PricewaterhouseCoopers Ltda.
     
15.2   Consent letter of Ryder Scott Company, L.P.
     
15.3   Consent letter of DeGolyer and MacNaughton.
     
16.1   Letter dated April 28, 2016 of PricewaterhouseCoopers Ltda., as required by Item 16F of Form 20-F.
     
99.1   Third-Party Reserve Report of Ryder Scott Company, L.P.
     
99.2   Third-Party Reserve Report of DeGolyer and MacNaughton.

 

11.Cross-reference to Form 20-F

 

        Sections
Item 1.   Identity of Directors, Senior Management and Advisers   N/A
         
Item 2.   Offer Statistics and Expected Timetable   N/A
         
Item 3.   Key Information    
         
    A. Selected Financial Data   1.3
         
    B. Capitalization and Indebtedness   N/A
         
    C. Reasons for the Offer and Use of Proceeds   N/A
         
    D. Risk Factors   5.1
         
Item 4.   Information on the Company   Note 1 to the consolidated financial statements
         
    A. History and Development of the Company   2.1; 3.1; Note 1 to the consolidated financial statements
         
    B. Business Overview   2; 3.3 – 3.9; 4.5.1
         
    C. Organizational Structure   3.2

 

 153 

 

 

        Sections
    D. Property, Plants and Equipment   3.4 – 3.6; 4.6.2; Notes 15 and 18 to the consolidated financial statements
         
    E. Oil and Gas Disclosures   3.3 – 3.6; Notes 16 and 18 and Supplemental information on Oil and Gas producing activities (unaudited by PwC) to the consolidated financial statements
         
Item 4A.   Unresolved Staff Comments   None
         
Item 5.   Operating and Financial Review and Prospects    
         
    A. Operating Results   3.8; 4.2; 4.5; 4.7; 5.1; 5.2
         
    B. Liquidity and Capital Resources   2.1; 4.6; 4.8; Notes 1, 6, 11, 20, 30 and 31.5 to the consolidated financial statements
         
    C. Research and development, Patents and Licenses, etc.   3.7; Note 17 to the consolidated financial statements
         
    D. Trend Information   4.10
         
    E. Off-Balance Sheet Arrangements   4.9
         
    F. Tabular Disclosure of Contractual Obligations   4.8
         
    G. Safe Harbor   1.2
         
Item 6.   Directors, Senior Management and Employees    
         
    A. Directors and Senior Management   7.3; 7.5
         
    B. Compensation   7.6; Notes 4, 15, 22 and 32 to the consolidated financial statements
         
    C. Board Practices   7.3
         
    D. Employees   3.12
         
    E. Share Ownership   7.7
         
Item 7.   Major Shareholders and Related Party Transactions    
         
    A. Major Shareholders   6.3; 6.8; 7.7
         
    B. Related Party Transactions   3.10; Note 32 to the consolidated financial statements
         
    C. Interests of Experts and Counsel   N/A
         
Item 8.   Financial Information    
         
    A. Consolidated Statements and Other Financial Information   3.4; 4; 5.3; 6.2; 8; Note 23 to the consolidated financial statements

 

 154 

 

 

        Sections
    B. Significant Changes   7.8; Note 36 to the consolidated financial statements
         
Item 9.   The Offer and Listing    
         
    A. Offer and Listing Details   6.3
         
    B. Plan of Distribution   N/A
         
    C. Markets   6.3
         
    D. Selling Shareholders   N/A
         
    E. Dilution   N/A
         
    F. Expenses of the Issue   N/A
         
Item 10.   Additional Information    
         
    A. Share Capital   N/A
         
    B. Memorandum and Articles of Association   7.1
         
    C. Material Contracts   3.4.4; 4.8; Exhibits 4.1 – 4.12
         
    D. Exchange Controls   5.1.4; 6.6
         
    E. Taxation   4.2.1; 6.5; Note 9 to the consolidated financial statements
         
    F. Dividends and Paying Agents   N/A
         
    G. Statements by Experts   N/A
         
    H. Documents On Display   1.1
         
    I. Subsidiary Information   N/A
         
Item 11.   Quantitative and Qualitative Disclosures About Market Risk   4.10; 5.1.1; 5.2.1; 5.2.3; Note 31 to the consolidated financial statements
         
Item 12.   Description of Securities Other than Equity Securities    
         
    A. Debt Securities   N/A
         
    B. Warrants and Rights   N/A
         
    C. Other Securities   N/A
         
    D. American Depositary Shares   6.4
         
Item 13.   Defaults, Dividend Arrearages and Delinquencies   None
         
Item 14.   Material Modifications to the Rights of Security Holders and Use of Proceeds   None

 

 155 

 

 

        Sections
         
Item 15.   Controls and Procedures   5.2; 7.8
         
Item 16A.   Audit Committee Financial Expert   7.3.2
         
Item 16B.   Code of Ethics   7.2; 7.4
         
Item 16C.   Principal Accountant Fees and Services   7.8
         
Item 16D.   Exemptions from the Listing Standards for Audit Committees   N/A
         
Item 16E.   Purchases of Equity Securities by the Issuer and Affiliated Purchases   N/A
         
Item 16F.   Changes in Registrant’s Certifying Accountant   7.8
         
Item 16G.   Corporate Governance   7.4
         
Item 16H.   Mine Safety Disclosure   N/A
         
Item 17   Financial Statements   N/A
         
Item 18.   Financial Statements   8
         
Item 19.   Exhibits   10

 

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