Annual Reports

  • 20-F (Mar 17, 2017)
  • 20-F (Mar 16, 2016)
  • 20-F (Mar 27, 2015)
  • 20-F (Mar 26, 2015)
  • 20-F (Mar 27, 2014)
  • 20-F (Mar 28, 2013)

 
Other

Total S.A. 20-F 2015
20-F
Table of Contents

 

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 

 

Form 20-F

 

 

(Mark One)

 

¨ REGISTRATION STATEMENT PURSUANT TO SECTION 12(b) OR 12(g) OF THE SECURITIES EXCHANGE ACT OF 1934

OR

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

For the fiscal year ended December 31, 2014

OR

 

¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the transition period from              to             

OR

 

¨ SHELL COMPANY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 Date of event requiring this shell company report

Commission file number: 1-10888

 

 

TOTAL S.A.

(Exact Name of Registrant as Specified in Its Charter)

Republic of France

(Jurisdiction of Incorporation or Organization)

2, place Jean Millier

La Défense 6

92400 Courbevoie

France

(Address of Principal Executive Offices)

Patrick de La Chevardière

Chief Financial Officer

TOTAL S.A.

2, place Jean Millier

La Défense 6

92400 Courbevoie

France

Tel: +33 (0)1 47 44 45 46

Fax: +33 (0)1 47 44 49 44

(Name, Telephone, Email 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

Shares    New York Stock Exchange*
American Depositary Shares    New York Stock Exchange

 

* Not for trading, but only in connection with the registration of American Depositary Shares, pursuant to the requirements of the Securities and Exchange Commission.

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.

2,385,267,525 Shares, par value 2.50 each, as of December 31, 2014

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.    Yes  þ    No  ¨

If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934.    Yes  ¨    No  þ

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  þ    No  ¨

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

Yes  ¨    No  ¨

 

** This requirement is not currently applicable to the registrant.

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  þ   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  ¨  

International Financial Reporting Standards as issued by the International

Accounting Standards Board  þ

   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.    Item17  ¨    Item 18   ¨

If this is an annual report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No  þ

 

 


Table of Contents

TABLE OF CONTENTS

 

     Page  

CERTAIN TERMS

     i   

ABBREVIATIONS

     ii   

CONVERSION TABLE

     ii   

CAUTIONARY STATEMENT CONCERNING FORWARD-LOOKING STATEMENTS

     iii   

Item 1.

  

Identity of Directors, Senior Management and Advisers

     1   

Item 2.

  

Offer Statistics and Expected Timetable

     1   

Item 3.

  

Key Information

     1   
  

Selected Financial Data

     1   
  

Exchange Rate Information

     2   
  

Risk Factors

     2   

Item 4.

  

Information on the Company

     9   
  

History and Development

     9   
  

Business Overview

     9   
  

Other Matters

     46   

Item 4A.

  

Unresolved Staff Comments

     88   

Item 5.

  

Operating and Financial Review and Prospects

     89   

Item 6.

  

Directors, Senior Management and Employees

     101   
  

Directors and Senior Management

     101   
  

Compensation

     109   
  

Corporate Governance

     128   
  

Employees and Share Ownership

     140   

Item 7.

  

Major Shareholders and Related Party Transactions

     144   

Item 8.

  

Financial Information

     146   

Item 9.

  

The Offer and Listing

     150   

Item 10.

  

Additional Information

     151   

Item 11.

  

Quantitative and Qualitative Disclosures About Market Risk

     167   

Item 12.

  

Description of Securities Other than Equity Securities

     167   

Item 13.

  

Defaults, Dividend Arrearages and Delinquencies

     168   

Item 14.

  

Material Modifications to the Rights of Security Holders and Use of Proceeds

     168   

Item 15.

  

Controls and Procedures

     168   

Item 16A.

  

Audit Committee Financial Expert

     168   

Item 16B.

  

Code of Ethics

     168   

Item 16C.

  

Principal Accountant Fees and Services

     169   

Item 16D.

  

Exemptions from the Listing Standards for Audit Committees

     169   

Item 16E.

  

Purchases of Equity Securities by the Issuer and Affiliated Purchasers

     170   

Item 16F.

  

Change in Registrant’s Certifying Accountant

     170   

Item 16G.

  

Corporate Governance

     170   

Item 16H.

  

Mine Safety Disclosure

     173   

Item 17.

  

Financial Statements

     173   

Item 18.

  

Financial Statements

     173   

Item 19.

  

Exhibits

     173   


Table of Contents

Basis of presentation

Financial information included in this Annual Report is presented according to International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB) and IFRS as adopted by the European Union (EU) as of December 31, 2014.

Statements regarding competitive position

Unless otherwise indicated, statements made in “Item 4. Information on the Company” referring to TOTAL’s competitive position are based on the Company’s estimates, and in some cases rely on a range of sources, including investment analysts’ reports, independent market studies and TOTAL’s internal assessments of market share based on publicly available information about the financial results and performance of market participants.

Additional information

This Annual Report on Form 20-F reports information primarily regarding TOTAL’s business, operations and financial information relating to the fiscal year ended December 31, 2014. For more recent updates regarding TOTAL, you may inspect any reports, statements or other information TOTAL files with the United States Securities and Exchange Commission (“SEC”). All of TOTAL’s SEC filings made after December 31, 2001, are available to the public at the SEC website at http://www.sec.gov and from certain commercial document retrieval services. See also “Item 10 — 7. Documents on Display”.

No material on the TOTAL website forms any part of this Annual Report on Form 20-F. References in this document to documents on the TOTAL website are included as an aid to their location and are not incorporated by reference into this document.

Certain terms

Unless the context indicates otherwise, the following terms have the meanings shown below:

 

“acreage”

The area, expressed in acres, over which TOTAL has interests in exploration or production.

 

“ADRs”

American Depositary Receipts evidencing ADSs.

 

“ADSs”

American Depositary Shares representing the shares of TOTAL S.A.

 

“association”/“consortium”/“joint venture”

Terms used to generally describe a project in which two or more entities participate. For the principles and methods of consolidation applicable to different types of joint arrangements according to IFRS, refer to Note 1 to the Consolidated Financial Statements.

 

“barrels”

Barrels of crude oil, condensates, NGL or bitumen.

 

“Company”

TOTAL S.A.

 

“condensates”

Condensates are a mixture of hydrocarbons that exist in a gaseous phase at original reservoir temperature and pressure, but that, when produced, exist in a liquid phase at surface temperature and pressure. Condensates are sometimes referred to as C5+.

 

“crude oil”

Crude oil is a mixture of compounds (mainly pentanes and heavier hydrocarbons) that exists in a liquid phase at original reservoir temperature and pressure and remains liquid at atmospheric pressure and ambient temperature. “Crude oil” or “oil” are sometimes used as generic terms to designate crude oil plus condensates plus NGL.

 

“Depositary”

JP Morgan Chase Bank, N.A.

 

“Depositary Agreement”

The depositary agreement pursuant to which ADSs are issued, a copy of which is attached as Exhibit (a) to the registration statement on Form F-6 (Reg. No. 333-199737) filed with the SEC on October 31, 2014.

 

“ERMI”

The ERMI (European Refining Margin Indicator) is a Group indicator intended to represent the refining margin after variable costs for a theoretical complex refinery located around Rotterdam in Northern Europe that processes a mix of crude oil and other inputs commonly supplied to this region to produce and market the main refined products at prevailing prices in the region.

 

“Group”

TOTAL S.A. and its subsidiaries and affiliates. The terms TOTAL and Group are used interchangeably.

 

“hydrocracker”

A refinery unit which uses a catalyst and extraordinarily high pressure, in the presence of surplus hydrogen, to shorten molecules.

 

“liquids”

Liquids consist of crude oil, bitumen, condensates and NGL.

 

“LNG”

Liquefied natural gas.

 

“LPG”

Liquefied petroleum gas is a mixture of hydrocarbons, the principal components of which are propane and butane, in a gaseous state at atmospheric pressure, but which is liquefied under moderate pressure and ambient temperature. LPG is included in NGL.

 

“NGL”

Natural gas liquids (NGL) are a mixture of light hydrocarbons that exist in the gaseous phase at atmospheric pressure and are recovered as liquids in gas processing plants; NGL include very light hydrocarbons (ethane, propane and butane).

 

“oil and gas”

Generic term which includes all hydrocarbons (e.g., crude oil, condensates, NGL, bitumen and natural gas).

 

2014 Form 20-F TOTAL S.A.   i


Table of Contents

“project”

As used in this report, “project” may encompass different meanings, such as properties, agreements, investments, developments, phases, activities or components, each of which may also informally be described as a “project”. Such use is for convenience only and is not intended as a precise description of the term “project” as it relates to any specific governmental law or regulation.

 

“proved reserves”

Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations, prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The full definition of “proved reserves” that we are required to follow in presenting such information in our financial results and elsewhere in reports we file with the SEC is found in Rule 4-10 of Regulation S-X under the U.S. Securities Act of 1933, as amended (including as amended by the SEC “Modernization of Oil and Gas Reporting” Release No. 33-8995 of December 31, 2008) (“Rule 4-10”).

 

“proved developed reserves”

Proved developed oil and gas reserves are proved reserves that can be expected to be recovered (i) through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and (ii) through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well. The full definition of “developed reserves” that we are required to follow in presenting such information in our financial results and elsewhere in reports we file with the SEC is found in Rule 4-10.

 

“proved undeveloped reserves”

Proved undeveloped oil and gas reserves are proved reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion. The full definition of “undeveloped reserves” that we are required to follow in presenting such information in our financial results and elsewhere in reports we file with the SEC is found in Rule 4-10.

 

“steam cracker”

A petrochemical plant that turns naphtha and light hydrocarbons into ethylene, propylene, and other chemical raw materials.

 

“TOTAL”

TOTAL S.A. and its subsidiaries and affiliates. We use such term interchangeably with the term Group. When we refer to the parent holding company alone, we use the term TOTAL S.A. or the Company.

 

“trains”

Facilities for converting, liquefying, storing and off-loading natural gas.

 

“turnarounds”

Temporary shutdowns of facilities for maintenance, overhaul and upgrading.

Abbreviations

 

b

  = barrel   boe   = barrel of oil equivalent   cf   = cubic feet   GWh   = gigawatt-hour

t

  = metric ton   m3   = cubic meter   Btu   = British thermal unit   TWh   = terawatt-hour

/d

  = per day   /y   = per year   k   = thousand   Wp   = watt peak

M

  = million   B   = billion   W   = watt    

Conversion table

 

1 acre

   = 0.405 hectares   

1 b

   = 42 U.S. gallons   

1 boe

   = 1 b of crude oil    = 5,400 cf of gas in 2014(1) (5,403 cf in 2013 and 5,434 cf in 2012)

1 b/d of crude oil

   = approximately 50 t/y of crude oil   

1 Bm3/y

   = approximately 0.1 Bcf/d   

1 m3

   = 35.3147 cf   

1 kilometer

   = approximately 0.62 miles   

1 ton

   = 1 t    = 1,000 kilograms (approximately 2,205 pounds)

1 ton of oil

   = 1 t of oil    = approximately 7.5 b of oil (assuming a specific gravity of 37° API)

1 Mt of LNG

   = approximately 48 Mcf of gas   

1 Mt/y LNG

   = approximately 131 Mcf/d   

 

(1) 

Natural gas is converted to barrels of oil equivalent using a ratio of cubic feet of natural gas per one barrel. This ratio is based on the actual average equivalent energy content of TOTAL’s natural gas reserves during the applicable periods, and is subject to change. The tabular conversion rate is applicable to TOTAL’s natural gas reserves on a group-wide basis.

 

ii   TOTAL S.A. Form 20-F 2014


Table of Contents

Cautionary statement concerning forward-looking statements

TOTAL has made certain forward-looking statements in this document and in the documents referred to in, or incorporated by reference into, this Annual Report. Such statements are subject to risks and uncertainties. These statements are based on the beliefs and assumptions of the management of TOTAL and on the information currently available to such management. Forward-looking statements include information concerning forecasts, projections, anticipated synergies, and other information concerning possible or assumed future results of TOTAL, and may be preceded by, followed by, or otherwise include the words “believes”, “expects”, “anticipates”, “intends”, “plans”, “targets”, “estimates” or similar expressions.

Forward-looking statements are not assurances of results or values. They involve risks, uncertainties and assumptions. TOTAL’s future results and share value may differ materially from those expressed in these forward-looking statements. Many of the factors that will determine these results and values are beyond TOTAL’s ability to control or predict. Except for its ongoing obligations to disclose material information as required by applicable securities laws, TOTAL does not have any intention or obligation to update forward-looking statements after the distribution of this document, even if new information, future events or other circumstances have made them incorrect or misleading.

You should understand that various factors, certain of which are discussed elsewhere in this document and in the documents referred to in, or incorporated by reference into, this document, could affect the future results of TOTAL and could cause results to differ materially from those expressed in such forward-looking statements, including:

 

   

material adverse changes in general economic conditions or in the markets served by TOTAL, including changes in the prices of oil, natural gas, refined products, petrochemical products and other chemicals;

   

changes in currency exchange rates and currency devaluations;

   

the success and the economic efficiency of oil and natural gas exploration, development and production programs, including, without limitation, those that are not controlled and/or operated by TOTAL;

   

uncertainties about estimates of changes in proven and potential reserves and the capabilities of production facilities;

   

uncertainties about the ability to control unit costs in exploration, production, refining and marketing (including refining margins) and chemicals;

   

changes in the current capital expenditure plans of TOTAL;

   

the ability of TOTAL to realize anticipated cost savings, synergies and operating efficiencies;

   

the financial resources of competitors;

   

changes in laws and regulations, including tax and environmental laws and industrial safety regulations;

   

the quality of future opportunities that may be presented to or pursued by TOTAL;

   

the ability to generate cash flow or obtain financing to fund growth and the cost of such financing and liquidity conditions in the capital markets generally;

   

the ability to obtain governmental or regulatory approvals;

   

the ability to respond to challenges in international markets, including political or economic conditions (including national and international armed conflict) and trade and regulatory matters (including actual or proposed sanctions on companies that conduct business in certain countries);

   

the ability to complete and integrate appropriate acquisitions, strategic alliances and joint ventures;

   

changes in the political environment that adversely affect exploration, production licenses and contractual rights or impose minimum drilling obligations, price controls, nationalization or expropriation, and regulation of refining and marketing, chemicals and power generating activities;

   

the possibility that other unpredictable events such as labor disputes or industrial accidents will adversely affect the business of TOTAL; and

   

the risk that TOTAL will inadequately hedge the price of crude oil or finished products.

For additional factors, you should read the information set forth under “Item 3 — C. Risk Factors”, “Item 4 — C. Other Matters”, “Item 5. Operating and Financial Review and Prospects” and “Item 11. Quantitative and Qualitative Disclosures About Market Risk”.

 

2014 Form 20-F TOTAL S.A.   iii


Table of Contents

Items 1 - 3

ITEM 1. IDENTITY OF DIRECTORS, SENIOR MANAGEMENT AND ADVISERS

Not applicable.

ITEM 2. OFFER STATISTICS AND EXPECTED TIMETABLE

Not applicable.

ITEM 3. KEY INFORMATION

 

 

A. SELECTED FINANCIAL DATA

 

 

The following table presents selected consolidated financial data for TOTAL on the basis of IFRS as issued by the IASB and IFRS as adopted by the EU for the years ended December 31, 2014, 2013, 2012, 2011 and 2010. Effective January 1, 2014, TOTAL changed the presentation currency of the Group’s Consolidated Financial Statements from the Euro to the US Dollar. Comparative 2013, 2012, 2011 and 2010 information in the table below has been restated. For more information, see the Introduction to the Consolidated Financial Statements. Following the retrospective application of the accounting interpretation IFRIC 21 effective January 1, 2014, the information for 2013 and 2012 has been restated; however, the impact on such restated results is not significant (for further information concerning this restatement, see the introduction to the Notes to the Consolidated Financial Statements included elsewhere herein). Ernst & Young Audit and KPMG S.A., independent registered public accounting firms and the Company’s auditors, audited the historical consolidated financial statements of TOTAL for these periods from which the financial data presented below for such periods are derived, except for the application of the revised accounting standard IAS 19 for the year 2010 and for the application of IFRIC 21 and change of presentation currency for the years 2010 and 2011. All such data should be read in conjunction with the Consolidated Financial Statements and the Notes thereto included elsewhere herein.

SELECTED CONSOLIDATED FINANCIAL DATA

 

(M$, except share and per share data)(a)    2014     2013      2012      2011      2010  

INCOME STATEMENT DATA

             

Revenues from sales

     212,018        227,969         234,216         231,830         186,232   

Net income, Group share

     4,244        11,228         13,648         17,400         14,740   

Earnings per share

     1.87        4.96         6.05         7.74         6.60   

Fully diluted earnings per share

     1.86        4.94         6.02         7.71         6.57   

CASH FLOW STATEMENT DATA

             

Cash flow from operating activities

     25,608        28,513         28,858         27,193         24,516   

Total expenditures

     30,509        34,431         29,475         34,161         21,574   

BALANCE SHEET DATA

             

Total assets

     229,798        239,223         225,886         211,793         191,641   

Non-current financial debt

     45,481        34,574         29,392         29,186         27,770   

Non-controlling interests

     3,201        3,138         1,689         1,749         1,144   

Shareholders’ equity — Group share

     90,330        100,241         93,969         86,667         79,748   

Common shares

     7,518        7,493         7,454         7,447         7,398   

DIVIDENDS

             

Dividend per share (euros)

     2.44 (b)      2.38         2.34         2.28         2.28   

Dividend per share (dollars)

     $3.00 (b)(c)      $3.24         $3.05         $2.97         $3.15   

COMMON SHARES(d)

             

Average number outstanding of common shares 2.50 par value (shares undiluted)

     2,272,859,512        2,264,349,795         2,255,801,563         2,247,479,529         2,234,829,043   

Average number outstanding of common shares 2.50 par value (shares diluted)

     2,281,004,151        2,271,543,658         2,266,635,745         2,256,951,403         2,244,494,576   

 

(a) 

Following the retrospective application of the accounting interpretation IFRIC 21 effective January 1, 2014, the information for 2013 has been restated; however, the impact on such restated results is not significant (for further information concerning this restatement, see the introduction to the Notes to the Consolidated Financial Statements included elsewhere herein).

(b) 

Subject to approval by the shareholders’ meeting on May 29, 2015.

(c) 

Estimated dividend in dollars includes the first quarterly interim ADR dividend of $0.77 paid in October 2014 and the second quarterly interim ADR dividend of $0.75 paid in January 2015, as well as the third quarterly interim ADR dividend of $0.74 payable in April 2015 and the proposed final interim ADR dividend of $0.74 payable in July 2015, both converted at a rate of $1.21/.

(d) 

The number of common shares shown has been used to calculate per share amounts.

 

2014 Form 20-F TOTAL S.A.   1


Table of Contents

Item 3

 

 

B. EXCHANGE RATE INFORMATION

 

 

 

For information regarding the effects of currency fluctuations on TOTAL’s results, see “Item 5. Operating and Financial Review and Prospects”.

Most currency amounts in this Annual Report on Form 20-F are expressed in U.S. dollars (“dollars” or “$”) or in euros (“euros” or “”). For the convenience of the reader, this Annual Report on Form 20-F presents certain translations into dollars of certain euro amounts ($1.30/1.00).

The following table sets out the average dollar/euro exchange rates expressed in dollars per 1.00 for the years indicated, based on an average of the daily European Central Bank (“ECB”) reference exchange rate.(1) Such rates are used by TOTAL in preparation of its Consolidated Statement of Income and Consolidated Statement of Cash Flow in its Consolidated Financial Statements. No representation is made that the euro could have been converted into dollars at the rates shown or at any other rates for such periods or at such dates.

DOLLAR/EURO EXCHANGE RATES

 

Year

   Average Rate  

2010

     1.3257   

2011

     1.3920   

2012

     1.2848   

2013

     1.3281   

2014

     1.3285   

The table below shows the high and low dollar/euro exchange rates for the four months ended December 31, 2014, and for the first months of 2015, based on the daily ECB reference exchange rates published during the relevant month expressed in dollars per 1.00.

DOLLAR/EURO EXCHANGE RATES

 

Period

   High      Low  

September 2014

     1.3151         1.2583   

October 2014

     1.2823         1.2524   

November 2014

     1.2539         1.2393   

December 2014

     1.2537         1.2141   

January 2015

     1.2043         1.1198   

February 2015

     1.1447         1.1240   

March 2015(a)

     1.1227         1.0557   

 

(a) 

Through March 24, 2015.

The ECB reference exchange rate on March 24, 2015 for the dollar against the euro was $1.0950/.

 

 

 

C. RISK FACTORS

 

 

 

The Group and its businesses are subject to various risks relating to changing competitive, economic, political, legal, social, industry, business and financial conditions. These conditions, along with TOTAL’s approaches to managing certain of these risks, are described below and discussed in greater detail elsewhere in this Annual Report, particularly under the headings “Item 4 — C. Other Matters”, “Item 5. Operating and Financial Review and Prospects” and “Item 11. Quantitative and Qualitative Disclosures About Market Risk”.

The operating results and future rate of growth of the Group are exposed to the effects of changing commodity prices.

Prices for oil and natural gas may fluctuate widely due to many factors over which TOTAL has no control. These factors include:

 

 

variations in global and regional supply and demand of energy;

 

global and regional economic and political developments in resource-producing regions, particularly in the Middle East, Africa and South America;

 

the ability of the Organization of the Petroleum Exporting Countries (OPEC) and other producing nations to influence global production levels and prices;

 

prices of unconventional energies as well as evolving approaches for developing oil sands and shale oil, which may affect the Group’s realized prices, notably under its long-term gas sales contracts and asset valuations, particularly in North America;

 

cost and availability of new technology;

 

governmental regulations and actions;

 

global economic and financial market conditions;

 

war or other conflicts;

 

changes in demographics, including population growth rates and consumer preferences; and

 

adverse weather conditions (such as hurricanes) that can disrupt supplies or interrupt operations of the Group’s facilities.

Substantial or extended declines in oil and natural gas prices would significantly and adversely affect TOTAL’s results of operations by reducing its profits. The year 2014 was marked by a sharp oil price decline in the second half, which continued in early 2015. For more detailed information on this oil price decline and its impact on the Group’s 2014 results, financial position and outlook, refer to “Item 5. Operating and Financial Review and Prospects”. For the year 2015, according to the scenarios retained, TOTAL estimates that a decrease of $10 per barrel in the average annual price of Brent crude would have the effect of reducing its annual cash flow from operations by approximately $2 billion, and vice versa (Brent price of $60 per barrel). In addition to the adverse effect on revenues, margins and profitability from any fall in oil and natural gas prices, a prolonged period of low prices or other indicators could lead to a review of the Group’s assets and oil and natural gas reserves. Such review would reflect the Company’s view based on estimates, assumptions and judgments and could result in a reduction in the Group’s reported reserves and/or a charge for impairment that could have a significant effect on the Group’s results in the period in which it occurs. Lower oil and natural gas prices over prolonged periods may also reduce the

 

 

 

(1) 

For the period 2010 — 2014, the averages of the ECB reference exchange rates expressed in dollars per 1.00 on the last business day of each month during the relevant year are as follows: 2010 — 1.32; 2011 — 1.40; 2012 —1.29; 2013 —1.33; and 2014 — 1.32.

 

2   TOTAL S.A. Form 20-F 2014


Table of Contents

Item 3 - C. Risk Factors

economic viability of projects planned or in development, impact the asset sale program of the Group and reduce liquidity, thereby decreasing the Group’s ability to finance capital expenditures and/or causing it to cancel or postpone investment projects. If TOTAL is unable to follow through with investment projects, the Group’s opportunities for future revenue and profitability growth would be reduced, which could materially impact the Group’s financial condition.

Conversely, in a high oil and gas price environment, the Group can experience significant increases in cost and government take, and, under some production-sharing contracts, the Group’s production rights could be reduced. Higher prices can also reduce demand for the Group’s products.

The Group’s earnings from its Refining & Chemicals and Marketing & Services segments are primarily dependent upon the supply and demand for refined products and the associated margins on refined product sales, with the impact of changes in oil and gas prices on earnings on these segments being dependent upon the speed at which the prices of refined products adjust to reflect movements in oil and gas prices. For the year 2015, according to the scenarios retained, TOTAL estimates that a decrease in the Group’s European Refining Margin Indicator (“ERMI”) of $1.00 per ton would decrease its annual cash flow from operations by approximately $0.07 billion, and vice versa.

The Group’s long-term profitability depends on cost effective discovery, acquisition and development of new reserves; if the Group is unsuccessful, its results of operations and financial condition would be materially and adversely affected.

A significant portion of the Group’s revenues and the majority of its operating results are derived from the sale of oil and gas that the Group extracts from underground reserves developed as part of its Exploration & Production activities. The development of oil and gas fields, the construction of facilities and the drilling of production or injection wells is capital intensive and requires advanced technology. Due to constantly changing market conditions and difficult environmental challenges, cost projections can be uncertain. In order for the Upstream segment to continue to be profitable, the Group needs to replace its reserves with new proved reserves. Furthermore, the Group needs to accomplish such replacement in a manner that allows subsequent production to be economically viable. However, TOTAL’s ability to discover or acquire and develop new reserves successfully is uncertain and can be negatively affected by a number of factors, including:

 

 

the geological nature of oil and gas fields, notably unexpected drilling conditions including pressure or irregularities in geological formations;

 

the risk of dry holes or failure to find expected commercial quantities of hydrocarbons;

 

the inability of service companies to deliver on contracted services;

 

the inability of the Group’s partners to execute or finance projects in which the Group holds an interest;

 

equipment failures, fires, blow-outs or accidents;

 

the Group’s inability to develop or implement new technologies that enable access to previously inaccessible fields;

 

the Group’s inability to anticipate market changes in a timely manner;

 

adverse weather conditions;

 

compliance with both anticipated and unanticipated governmental requirements, including U.S. and EU

 

regulations that may give a competitive advantage to companies not subject to such regulations;

 

shortages or delays in the availability or delivery of appropriate equipment;

 

industrial action;

 

competition from oil and gas companies for the acquisition and development of assets and licenses (see “Item 4 — C. Other Matters — 5. Competition”);

 

increased taxes and royalties, including retroactive claims; and

 

disputes related to property titles.

Any of these factors could lead to cost overruns and impair the Group’s ability to make discoveries and acquisitions or complete a development project, or to make production economical. It is impossible to guarantee that new reserves of oil and gas will be discovered or acquired in sufficient quantities to replace the Group’s reserves currently being developed, produced and marketed.

Furthermore, some of these factors may also affect the Group’s projects and facilities further down the oil and gas chain. If TOTAL fails to develop new reserves cost-effectively on an ongoing basis, the Group’s results of operations, including profits, and the Group’s financial condition, would be materially and adversely affected.

The Group’s oil and gas reserves data are only estimates and subsequent downward adjustments are possible. If actual production from such reserves is lower than current estimates indicate, the Group’s results of operations and financial condition would be negatively impacted.

The Group’s proved reserves figures are estimates reflecting applicable reporting regulations. Proved reserves are those reserves which, by analysis of geosciences and engineering data, can be estimated with reasonable certainty to be economically recoverable — from a given date forward, from known reservoirs and under existing economic conditions, operating methods and government regulations — prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. Reserves are estimated by teams of qualified, experienced and trained geoscientists, petroleum engineers and project engineers, who rigorously review and analyze in detail all available geosciences and engineering data (e.g., seismic, electrical logs, cores, fluids, pressures, flow rates, facilities parameters). This process involves making subjective judgments, including with respect to the estimate of hydrocarbons initially in place, initial production rates and recovery efficiency, based on available geological, technical and economic data. Consequently, estimates of reserves are not exact measurements and are subject to revision. In addition, they may be negatively impacted by a variety of factors that are beyond the Group’s control and that could cause such estimates to be adjusted downward in the future, or cause the Group’s actual production to be lower than its currently reported proved reserves indicate. The main such factors include:

 

 

a decline in the price of oil or gas, making reserves no longer economically viable to exploit and therefore not classifiable as proved;

 

an increase in the price of oil or gas, which may reduce the reserves to which the Group is entitled under production sharing and risked service contracts and other contractual terms;

 

changes in tax rules and other government regulations that make reserves no longer economically viable to exploit; and

 

the actual production performance of the Group’s reservoirs.

 

 

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The Group’s proved reserves based on SEC rules were 11,523 Mboe at December 31, 2014, based on the average monthly Brent price of $101.3/b. If the Brent price were to continue to remain low in 2015 compared to 2014, proved reserves at year-end 2015 could decline.

The Group’s reserves estimates may therefore require substantial downward revisions to the extent its subjective judgments prove not to have been conservative enough based on the available geosciences and engineering data, or the Group’s assumptions regarding factors or variables that are beyond its control prove to be incorrect over time. Any downward adjustment would indicate lower future production amounts, which could adversely affect the Group’s results of operations, including profits as well as its financial condition.

The Group’s production growth depends on the delivery of its major development projects.

The Group’s targeted production growth relies heavily on the successful execution of major development projects that are increasingly complex and capital-intensive. These major projects are subject to a number of challenges, including:

 

 

negotiations with partners, governments, suppliers, customers and others;

 

cost overruns and delays related to the availability of skilled labor or delays in manufacturing and delivery of critical equipment, or shortages in the availability of such equipment;

 

unforeseen technical difficulties that could delay project startup or cause unscheduled project downtime;

 

the actual performance of the reservoir and natural field decline; and

 

timely issuance or renewal of permits and licenses by government agencies.

Poor delivery of any major project that underpins production or production growth could adversely affect the Group’s financial performance.

Many of the Group’s projects are conducted by equity affiliates. This may reduce the Group’s degree of control, as well as its ability to identify and manage risks.

A significant and growing number of the Group’s projects are conducted by equity affiliates. In cases where the Group’s company is not the operator, such company may have limited influence over, and control of, the behavior, performance and costs of the partnership, its ability to manage risks may be limited and it may, nevertheless, be prosecuted by regulators or claimants in the event of an incident. Additionally, the partners of the Group may not be able to meet their financial or other obligations to the projects, which may threaten the viability of a given project. These partners may also not have the financial capacity to fully indemnify the Group in the event of an incident.

For additional information concerning equity affiliates, refer to Note 12 (“Equity affiliates: investments and loans”) to the Consolidated Financial Statements.

TOTAL has significant production and reserves located in politically, economically and socially unstable areas, where the likelihood of material disruption of the Group’s operations is relatively high.

A significant portion of TOTAL’s oil and gas production and reserves is located in countries outside of the Organisation for Economic Co-operation and Development (OECD). In recent years, a number of these countries have experienced varying degrees of one or more of the following: economic instability, political volatility, civil war, violent conflict, social unrest, actions of terrorist groups

 

and the application of international economic sanctions. Any of these conditions alone or in combination could disrupt the Group’s operations in any of these regions, causing substantial declines in production or revisions to reserves estimates. In Africa, which represented 31% of the Group’s 2014 combined liquids and gas production, certain of the countries in which the Group has production have recently suffered from some of these conditions, including Nigeria, which has been the main contributing country to the Group’s production of hydrocarbons since 2012, and Libya. The Middle East, which represented 18% of the Group’s 2014 combined liquids and gas production, has in recent years suffered increased political volatility in connection with violent conflict and social unrest, including Syria, where European Union (EU) and U.S. economic sanctions have prohibited TOTAL from producing oil and gas since 2011, and Yemen. In South America, which represented 7% of the Group’s 2014 combined liquids and gas production, certain of the countries in which TOTAL has production have recently suffered from some of the above-mentioned conditions, including Argentina and Venezuela. In Russia, where, as of December 31, 2014, the Group held 19% of its proved reserves, members of the international community have, since July 2014, adopted economic sanctions against certain Russian persons and entities, including various entities operating in the financial, energy and defense sectors, in response to the situation in Ukraine (for additional information, refer to “—Restrictions against Russia”, below). Furthermore, in addition to current production, TOTAL is also exploring for and developing new reserves in other regions of the world that are historically characterized by political, social and economic instability, such as the Caspian Sea region where TOTAL has large projects currently underway. The occurrence and magnitude of incidents related to economic, social and political instability are unpredictable. It is possible that they could have a material adverse impact on the Group’s production and operations in the future and/or cause certain investors to reduce their holdings of TOTAL’s securities.

TOTAL, like other major international energy companies, has a geographically diverse portfolio of reserves and operational sites, which allows it to conduct its business and financial affairs so as to reduce its exposure to political and economic risks. However, there can be no assurance that such events will not have a material adverse impact on the Group.

TOTAL’s activities are subject to intervention by the government of host countries, which could have an adverse effect on the Group’s results of operations.

TOTAL has significant exploration and production activities, and in some cases refining, marketing or chemicals operations, in countries whose governmental and regulatory framework is subject to unexpected change and where the enforcement of contractual rights is uncertain. In addition, the Group’s exploration and production activities in such countries are often done in conjunction with state-owned entities, for example as part of a joint venture, where the state has a significant degree of control. In recent years, in various regions globally, TOTAL has seen governments and state-owned enterprises imposing more stringent conditions on companies pursuing exploration and production activities in their respective countries, increasing the costs and uncertainties of the Group’s business operations, which is a trend TOTAL expects to continue.

Potential increasing intervention by governments in such countries can take a wide variety of forms, including:

 

 

the award or denial of exploration and production interests;

 

the imposition of specific drilling obligations;

 

price and/or production quota controls and export limits;

 

 

4   TOTAL S.A. Form 20-F 2014


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Item 3 - C. Risk Factors

 

nationalization or expropriation of assets;

 

unilateral cancellation or modification of license or contract rights;

 

increases in taxes and royalties, including retroactive claims;

 

the renegotiation of contracts;

 

the imposition of increased local content requirements;

 

payment delays; and

 

currency exchange restrictions or currency devaluation.

Imposition of any of these factors by a host government where TOTAL has substantial operations, including exploration, could cause the Group to incur material costs or cause the Group’s production or value of the Group’s assets to decrease, potentially having a material adverse effect on its results of operations, including profits.

For example, the Nigerian government has been contemplating new legislation to govern the petroleum industry which, if passed into law, could have an impact on the existing and future activities of the Group in that country through increased taxes and/or costs of operation and could adversely affect financial returns from projects in that country.

Ethical misconduct or breaches of applicable laws by employees of the Group could expose TOTAL to criminal and civil penalties and be damaging to TOTAL’s reputation and shareholder value.

The Group’s Code of Conduct, which applies to all of its employees, defines the Group’s commitment to business integrity, compliance with all applicable legal requirements and high ethical standards. The Code also defines the behavior and actions expected of the businesses and people of the Group wherever it operates. Ethical misconduct or non-compliance with applicable laws and regulations, including non-compliance with anti-bribery and anti-corruption laws, by TOTAL, its partners, agents or others that act on the Group’s behalf, could expose TOTAL and its employees to criminal and civil penalties and could be damaging to TOTAL’s reputation and shareholder value. In addition, ethical misconduct or non-compliance with applicable laws may lead the competent authorities to impose other measures, such as the appointment of an independent monitor in charge of reviewing the Group’s compliance and internal control procedures and, if need be, recommending improvements of such procedures. For an overview of the settlements between TOTAL, the SEC and the Department of Justice (DoJ) providing for the appointment of an independent monitor, refer to “Item 4 — C. Other Matters — 7.3.7.1. Preventing corruption” and “Item 8 — 4. Legal or arbitration proceedings — 4. Iran”.

TOTAL is exposed to risks related to the safety and security of its operations.

TOTAL engages in a broad range of industrial activities, including, in particular, drilling, oil and gas production, processing, transportation, refining and petrochemical activities, storage and distribution of petroleum products, specialty chemicals and solar energy. These activities involve a wide range of operational risks, such as explosions, fires, accidents, equipment failures, leakage of toxic products, emissions or discharges into the air, water or soil, and related environmental and health risks. In the transportation area, the type of risk depends not only on the hazardous nature of the products transported, but also on the transportation methods used (mainly maritime, river-maritime, rail, road and pipelines), the volumes involved and the sensitivity of the regions through which the transport passes (quality of infrastructure, population density, environmental considerations). Moreover, most of the Group’s activities will eventually require environmental site remediation, closure and decommissioning after operations are discontinued.

The industrial events that could have the most significant impact are primarily:

 

 

a major industrial accident (fire, explosion, leakage of highly toxic products); and

 

large-scale accidental pollution or pollution at a particularly sensitive site.

Each of the described risks corresponds to events that could potentially cause death, harm human health, damage property, disrupt business activities or cause environmental damage. The Group’s employees, contractors, residents living near the facilities or customers can suffer injuries. Property damage can involve the facilities of the Group as well as the property of third parties. The seriousness of the consequences of these events varies according to the vulnerability of the people, ecosystems and business activities impacted, on the one hand, and the number of people in the impact area and the location of the ecosystems and business activities in relation to TOTAL’s facilities or to the trajectory of the products after the event, on the other hand.

Acts of terrorism against the Group’s plants and sites, pipelines, transportation and computer systems could also severely disrupt business activities and could cause harm to people, the environment and property.

Like most industrial groups, TOTAL is affected by reports of occupational illnesses, particularly those caused by past exposure of the Group’s employees to asbestos. Asbestos exposure has been subject to close monitoring at all of the Group’s business segments. As of December 31, 2014, the Group estimates that the ultimate cost of all pending or future asbestos-related claims is not likely to have a material impact on the Group’s financial position.

Certain segments or activities of the Group face specific additional risks.

TOTAL’s Upstream segment faces, notably, risks related to the physical characteristics of oil and gas fields. These risks include eruptions of oil or gas, discovery of hydrocarbon pockets with abnormal pressure, crumbling of well openings, leaks that can harm the environment and explosions or fires. These events, which may cause injury, death or environmental damage, can also damage or destroy oil or gas wells as well as equipment and other property, lead to a disruption of the Group’s operations or reduce its production. In addition, since exploration and production activities may take place on sites that are ecologically sensitive (for example, in tropical forests or in a marine environment), each site requires a risk-based approach to avoid or minimize the impact on human health, flora and fauna, the ecosystem and biodiversity. In certain situations where the operator is not a Group entity, the Group may have reduced influence and control over third parties, which may limit its ability to manage and control these risks.

The activities of the Refining & Chemicals and Marketing & Services business segments also entail additional health, safety and environmental risks related to the overall life cycle of the products manufactured, as well as the materials used in the manufacturing process, such as catalysts, additives and monomers. These risks can arise from the intrinsic characteristics of the products involved (flammability, toxicity or long-term environmental impacts such as greenhouse gas emissions), their use (including by customers), emissions and discharges resulting from their manufacturing process (such as greenhouse gas emissions), and from material and waste disposal (recycling, regeneration or other processes, or waste elimination).

 

 

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Contracts signed by the Group’s entities may provide for indemnification obligations either by TOTAL in favor of the contractor or third parties or by the contractor or third parties in favor of TOTAL if, for example, an event occurs leading to death, personal injury or property or environmental damage.

With respect to joint ventures in which an entity of the Group has an interest and the assets of which are operated by such Group entity under an operating agreement between the joint venture and such entity, contractual terms generally provide that the operator assumes full liability for damages caused by its gross negligence or willful misconduct.

With respect to joint ventures in which an entity of the Group has an interest but the assets of which are operated by a third party, contractual terms generally provide that the operator assumes full liability for damages caused by its gross negligence or willful misconduct.

In the absence of the operator’s gross negligence or willful misconduct, other liabilities are generally borne by the joint venture and the cost thereof is assumed by the partners of the joint venture in proportion to their respective ownership interests.

With respect to third-party providers of goods and services, the amount and nature of the liability assumed by the third party depends on the context and may be limited by contract. With respect to their customers, the Group’s entities ensure that their products meet applicable specifications and abide by all applicable consumer protection laws. Failure to do so could lead to personal injury, environmental harm and loss of customers, which could negatively impact the Group’s results of operations, financial position and reputation.

Crisis management systems are necessary to respond effectively to emergencies, avoid potential disruptions in TOTAL’s business and operations, and minimize impacts on third parties and the environment.

TOTAL has crisis management plans in place to deal with emergencies. However, these plans cannot exclude the risk that the Group’s business and operations may be severely disrupted in a crisis situation or ensure the absence of impacts on third parties or the environment. TOTAL also has implemented business continuity plans in order to continue or resume operations following a shutdown or incident. An inability to restore or replace critical capacity in a timely manner could prolong the impact of any disruption and could have a material adverse effect on the Group’s business and operations. For more information on the Group’s crisis management systems, see “Item 4 — C. Other Matters — 1. Management and monitoring of industrial and environmental risks”.

While the Group’s insurance coverage is in line with industry practice, TOTAL is not insured against all possible risks.

The Group maintains insurance to protect itself against the risk of damage to Group property and/or business interruption to the Group’s main refining and petrochemical sites. In addition, the Group also maintains worldwide third-party liability insurance coverage for all of its subsidiaries. The Group’s insurance and risk management policies are described under “Item 4 — C. Other Matters — 2. Insurance and risk management”. TOTAL believes that its insurance coverage is in line with industry practice and sufficient to cover normal risks in its operations. However, the Group is not insured against all potential risks. In the event of a major environmental disaster, for example, TOTAL’s liability may exceed the maximum coverage provided by its third-party liability insurance. The loss TOTAL could suffer in the event of such disaster would depend on all the facts and circumstances of the

event and would be subject to a whole range of uncertainties, including legal uncertainty as to the scope of liability for consequential damages, which may include economic damage not directly connected to the disaster. The Group cannot guarantee that it will not suffer any uninsured loss and there can be no guarantee, particularly in the case of a major environmental disaster or industrial accident, that such loss would not have a material adverse effect on the Group.

TOTAL is subject to stringent environmental, health and safety laws in numerous countries and may incur material costs to comply with these laws and regulations.

TOTAL’s workforce and the public are exposed to risks inherent to the Group’s operations that potentially could lead to loss of life, injuries, property damage or environmental damage and could result in regulatory action and legal liability against the entities of the Group and its officers, as well as damage to the Group’s reputation.

TOTAL incurs, and will continue to incur, substantial expenditures to comply with increasingly complex laws and regulations aimed at protecting health, safety and the environment.

These expenditures include:

 

 

costs incurred to prevent, control, eliminate or reduce certain types of air and water emissions, including those costs incurred in connection with measures taken to address climate change;

 

remedial measures related to environmental contamination or accidents at various sites, including those owned by third parties;

 

indemnification of individuals or entities claiming damages caused by accidents or by the Group’s activities;

 

increased production costs and costs related to changes in product specifications; and

 

costs related to the decommissioning of drilling platforms and other facilities.

Such expenditures could have a material effect on the results of operations of the Group and its financial position.

Furthermore, in countries where the Group operates or plans to operate, the introduction of new laws and regulations, stricter enforcement or new interpretations of existing laws and regulations or the imposition of tougher license requirements may also cause the Group’s entities to incur higher costs resulting from actions taken to comply with such laws and regulations, including:

 

 

modifying operations;

 

installing complementary pollution control equipment;

 

implementing additional safety measures; and

 

performing site clean-ups.

As a further result of, notably, the introduction of any new laws and regulations, the Group could also be compelled to curtail, modify or cease certain operations or implement temporary shutdowns of facilities, which could diminish the Group’s productivity and have a material adverse impact on its results of operations.

All TOTAL entities monitor legal and regulatory developments in order to remain in compliance with local and international rules and standards for the assessment and management of industrial and environmental risks. With regard to the permanent shutdown of an activity, the Group’s environmental contingencies and asset retirement obligations are addressed in the “Asset retirement obligations” and “Provisions for environmental contingencies” sections of the Group’s Consolidated Balance Sheet (see Note 19 to the Consolidated Financial Statements). Future expenditures related to asset retirement obligations are accounted for in

 

 

6   TOTAL S.A. Form 20-F 2014


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Item 3 - C. Risk Factors

accordance with the accounting principles described in Note 1Q to the Consolidated Financial Statements.

Laws and regulations related to climate change and its physical effects may adversely affect the Group’s business.

Growing public concern in a number of countries over greenhouse gas emissions and climate change, as well as a multiplication of stricter regulations in this area, could adversely affect the Group’s businesses and product sales, increase its operating costs and reduce its profitability.

More of TOTAL’s future production could come from unconventional sources in order to help meet the world’s growing demand for energy. Since the energy intensity of oil and gas production from unconventional sources can be higher than that of production from conventional sources, the CO2 emissions produced by the Group’s activities may increase. Therefore, TOTAL may need to incur additional costs related to certain projects. For information concerning the regulation of CO2 emission allowances in Europe, see “Item 4 — C. Other Matters — 3.3.1. European Union — CO2 emission allowances”.

Finally, TOTAL’s businesses operate in varied locales where the potential physical impacts of climate change, including changes in weather patterns, are highly uncertain and may adversely impact the results of the Group’s operations.

TOTAL faces foreign exchange risks that could adversely affect its results of operations.

The Group faces foreign exchange risks because a large percentage of its revenues and cash receipts are denominated in dollars, the international currency of petroleum sales, while a significant portion of its operating expenses and income taxes accrue in euros and other currencies. Movements between the dollar and euro or other currencies may adversely affect the Group’s business by negatively impacting its booked revenues and income, and may also result in significant translation adjustments that impact its shareholders’ equity as the Group’s financial statements are presented in dollars.

The Group is exposed to trading risks that could adversely affect its business.

TOTAL’s trading business is particularly sensitive to market risk and more specifically to price risk as a consequence of the volatility of oil prices, to liquidity risk (inability to buy or sell oil cargoes at quoted prices) and to performance risk (counterparty does not fulfill its contractual obligations). The Group uses various instruments such as futures, forwards, swaps and options on organized markets or over-the-counter markets to hedge against fluctuations in the price of crude oil, refined products, natural gas, power, coal, emissions and freight-rates. Although TOTAL believes it has established appropriate risk management procedures, large market fluctuations may adversely affect the Group’s business and results of operations and make it more difficult to optimize revenues from the Group’s oil and gas production and to obtain favorable pricing to supply the Group’s refineries.

Disruption of the Group’s critical IT services or breaches of information security could adversely affect its operations.

The businesses of the Group depend heavily on the reliability and security of its information technology (“IT”) systems. If the integrity of the IT systems were compromised due to, for example, technical failure, or cyber attack, the Group’s business operations and assets could sustain serious damage, material intellectual property could be divulged and, in some cases, personal injury, environmental harm and regulatory violations could occur, potentially having a material adverse effect on the Group’s results of operations, including profits.

TOTAL’s IT department has developed and distributed governance and security rules that describe the recommended infrastructure, organization and procedures to maintain information systems that are appropriate to the organization’s needs and to limit information security risks. These rules are implemented across the Group under the responsibility of the various business segments.

TOTAL has activities in certain countries that are targeted by economic sanctions under relevant U.S. and EU laws, and if the Group’s activities are not conducted in accordance with the relevant conditions, TOTAL could be sanctioned or otherwise penalized.

Various members of the international community have targeted certain countries, including Cuba, Iran, Sudan, Syria and Russia, with economic sanctions and other restrictive measures. This section focuses on certain U.S. and European restrictions relevant to the Group. For certain disclosure concerning the Group’s limited activities or presence in certain targeted countries, refer to “Item 4 — C. Other Matters — 8. Cuba, Iran and Syria”.

The United States has adopted various laws and regulations designed to restrict trade with Cuba, Iran, Sudan and Syria, and the U.S. Department of State has identified these countries as state sponsors of terrorism. The European Union (“EU”) has similar restrictions with respect to Iran and Syria. Since mid-2014, both the United States and the EU have adopted economic sanctions against various persons and entities in Russia in response to the situation in Ukraine. A violation by the Group of applicable laws or regulations could result in criminal and material financial penalties.

The U.S. Treasury Department’s Office of Foreign Assets Control (referred to as “OFAC”) administers and enforces economic sanctions programs against the countries identified as state sponsors of terrorism, as well as other targeted countries, territories, entities and individuals, including those engaged in activities related to terrorism or the proliferation of weapons of mass destruction and other threats to the national security, foreign policy or economy of the United States. The activities that are restricted depend on the details of each particular sanctions program. Civil and criminal penalties, which are imposed on a per transaction basis for apparent violations, can be substantial. These OFAC sanctions apply to U.S. persons, activities taking place in the United States, and activities that are otherwise subject to U.S. jurisdiction.

TOTAL continues to closely monitor the possible impacts on all of its activities of the different economic sanctions regimes. TOTAL does not believe that its activities in targeted countries are in violation of applicable international economic sanctions administered by the United States, the European Union and other members of the international community. TOTAL cannot assure that current or future regulations or developments related to economic sanctions will not have a negative impact on its business or reputation.

Set forth below is additional information concerning U.S. and EU restrictions adopted against Iran, Syria and Russia.

 

 

Restrictions against Iran

With respect to Iran, the United States has adopted a number of measures since 1996 that provide for the possible imposition of sanctions against non-U.S. companies engaged in certain activities in and with Iran, including in Iran’s energy sector. The United States first adopted legislation in 1996 authorizing sanctions against non-U.S. companies doing business in Iran and Libya (the Iran and Libya Sanctions Act, referred to as “ILSA”). In 2006, ILSA was amended to concern only business in Iran (then renamed the Iran Sanctions Act, referred to as “ISA”). Pursuant to ISA, which has been amended and expanded since 1996, the

 

 

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President of the United States is authorized to initiate an investigation into the activities of non-U.S. companies in Iran’s energy sector and to impose sanctions against persons found, amongst other activities, to have knowingly made investments of $20 million or more in Iran’s petroleum sector in any 12-month period. In May 1998, the U.S. government waived the application of ISA sanctions for TOTAL’s investment in the South Pars gas field. This waiver, which has not been modified since it was granted, does not address any of TOTAL’s other activities in Iran. In each of the years between the passage of ILSA and 2007, TOTAL made investments in Iran in excess of $20 million (excluding the investments made as part of the development of South Pars). These investments will not be sanctioned by the U.S. authorities, provided that TOTAL meets certain commitments pursuant to a determination made by U.S. authorities under a “Special Rule” on September 30, 2010, as further described below. Since 2008, TOTAL’s position in Iran essentially has consisted of being reimbursed for its past investments as part of buyback contracts signed between 1995 and 1999 with respect to permits on which the Group is no longer the operator. Since 2011, TOTAL has had no production in Iran.

ISA was amended in July 2010 by the Comprehensive Iran Sanctions, Accountability and Divestment Act of 2010 (“CISADA”), which expanded both the list of activities with Iran that could lead to sanctions and the list of restrictive measures available. TOTAL had already discontinued potentially sanctionable sales of refined petroleum products to Iran prior to CISADA’s enactment. On September 30, 2010, the U.S. State Department announced that the U.S. government, pursuant to the “Special Rule” provision of ISA added by CISADA that allows it to avoid making a determination of sanctionability under ISA with respect to any party that provides certain assurances, would not make such a determination with respect to TOTAL. The U.S. State Department further indicated that, as long as TOTAL acts in accordance with its commitments, TOTAL will not be regarded as a company of concern for its past Iran-related activities.

Since the applicability of the “Special Rule” to TOTAL was announced by the U.S. State Department, the United States has imposed a number of additional measures targeting activities in Iran. TOTAL does not conduct activities that it believes would be sanctionable under these measures.

The Iran Threat Reduction and Syria Human Rights Act of 2012 (“ITRA”) added Section 13(r) to the Securities Exchange Act of 1934, as amended (“U.S. Exchange Act”), which requires TOTAL to disclose whether it or any of its affiliates has engaged during the calendar year in certain Iran-related activities, including those targeted under ISA, without regard to whether such activities are sanctionable under ISA, and any transaction or dealing with the Government of Iran that is not conducted pursuant to a specific authorization of the U.S. government (refer to “Item 4 — 8.1. Iran”, below). For any annual report that contains responsive Section 13(r) disclosure, an “Iran Notice” must be separately filed with the United States Securities and Exchange Commission (“SEC”). The SEC must notify the President and U.S. Congress, and the President must initiate an investigation and make a sanctions determination within 180 days after initiating the investigation. TOTAL believes that its Iran-related activities required to be disclosed by Section 13(r) are not sanctionable, and TOTAL has not been informed that it is at risk of possible imposition of sanctions for activities previously disclosed.

Moreover, many U.S. states have adopted legislation with respect to Iran requiring, in certain conditions, state pension funds to divest themselves of securities in any company with active business operations in Iran and state contracts not to be awarded

to such companies. State insurance regulators have adopted similar initiatives relating to investments by insurance companies in companies doing business with the Iranian oil and gas, nuclear and defense sectors. If TOTAL’s presence in Iran were determined to fall within the prohibited scope of these laws, and TOTAL were not to qualify for any available exemptions, certain U.S. institutions holding interests in TOTAL may be required to sell their interests. If significant, sales of securities resulting from such laws and/or regulatory initiatives could have an adverse effect on the prices of TOTAL’s securities.

The EU has also adopted sanctions measures with regard to Iran, including a set of restrictive measures adopted in July and October 2010. Among other things, the supply of key equipment and technology in the following sectors of the oil and gas industry in Iran are prohibited: refining, liquefied natural gas (LNG), exploration and production. The prohibition extends to technical assistance, training and financial assistance in connection with such items. Extension of loans or credit to, acquisition of shares in, entry into joint ventures with or other participation in enterprises in Iran (or Iranian-owned enterprises outside of Iran) engaged in any of the targeted sectors also is prohibited. Moreover, with respect to restrictions on transfers of funds and on financial services, any transfer of at least 400,000 or equivalent to or from an Iranian individual or entity shall require a prior authorization of the competent authorities of the EU Member States. TOTAL conducts its activities in compliance with these EU measures.

On January 23, 2012, the Council of the EU prohibited the purchase, import and transport of Iranian oil and petroleum and petrochemical products by European persons and by entities constituted under the laws of an EU Member State. Prior to that date, TOTAL had ceased these now-prohibited activities.

TOTAL continues to closely monitor the Joint Plan of Action announced late 2013 among Iran and the P5+1 countries (China, France, Russia, the United Kingdom and the United States, as well as Germany) regarding limits on Iran’s nuclear activities and the suspension of certain United States and EU sanctions regarding Iran. Negotiations between Iran and the P5+1 were extended in November 2014 and are ongoing.

 

 

Restrictions against Syria

With respect to Syria, the EU adopted measures in May 2011 that prohibit the supply of certain equipment to Syria, as well as certain financial and asset transactions with respect to a list of named individuals and entities. These measures apply to European persons and to entities constituted under the laws of an EU Member State. In September 2011, the EU adopted further measures, including, notably, a prohibition on the purchase, import or transportation from Syria of crude oil and petroleum products. Since early September 2011, the Group ceased to purchase hydrocarbons from Syria. On December 1, 2011, the EU extended sanctions against, among others, three state-owned Syrian oil firms, including General Petroleum Corporation, TOTAL’s co-contracting partner in the production sharing agreement signed in 1988 (Deir Ez Zor licence) and the Tabiyeh contract. The United States also has various measures regarding Syria. Since early December 2011, the Group has ceased its activities that contributed to oil and gas production in Syria.

 

 

Restrictions against Russia

Since July 2014, members of the international community have adopted economic sanctions against certain Russian persons and entities, including various entities operating in the financial, energy and defense sectors, in response to the situation in Ukraine.

 

 

8   TOTAL S.A. Form 20-F 2014


Table of Contents

Items 3 - 4

Among other things, OFAC has adopted economic sanctions targeting OAO Novatek, a Russian company listed on the Moscow Interbank Currency Exchange and the London Stock Exchange in which the Group held an 18.24% interest as of December 31, 2014 through its subsidiary TOTAL E&P Holdings Russia, and entities in which OAO Novatek (individually or with other similarly targeted persons or entities collectively) owns an interest of at least 50%. The OFAC sanctions applicable to OAO Novatek prohibit U.S. persons from transacting in, providing financing for or otherwise dealing in debt issued after July 16, 2014 of greater than 90 days maturity, including OAO Yamal LNG, which is jointly-owned by OAO Novatek (60%), TOTAL E&P Yamal (20%) and CNODC (20%), a subsidiary of CNPC. Consequently, the use of the U.S. dollar for such financing is effectively prohibited.

In order to comply with these sanctions, the financing plan for the Yamal LNG project is being reviewed, and the project’s partners are engaged in efforts to develop a financing plan in line with the applicable regulations.

TOTAL continues to closely monitor the different international economic sanctions with respect to its activities in Russia. Within this framework, the Group is filing the requests for prior authorizations required by EU restrictive measures concerning technical assistance, brokering services, financing and financial assistance related to certain technologies. The Treasury Department of the French Ministry of Finance, the competent authority on the subject, issued authorizations specifically for the projects of Yamal LNG, Kharyaga and Termokarstovoye. The United States has also imposed export controls and restrictions on the export of goods, services, and technologies for use in certain Russian energy projects that may affect TOTAL’s activities in Russia.

As of December 31, 2014, the Group held 19% of its proved reserves in Russia.

 

 

ITEM 4. INFORMATION ON THE COMPANY

 

 

A. HISTORY AND DEVELOPMENT

 

 

 

TOTAL S.A., a French société anonyme (limited liability company) incorporated in France on March 28, 1924, is, together with its subsidiaries and affiliates, the fourth largest publicly-traded integrated international oil and gas company(1).

With operations in more than 130 countries, TOTAL is engaged in every sector of the oil industry, including upstream (hydrocarbon exploration, development and production) and downstream (refining, petrochemicals, specialty chemicals, trading and shipping of crude oil and petroleum products and marketing). TOTAL also operates in the power generation and renewable energy sectors.

TOTAL began its Upstream operations in the Middle East in 1924. Since then, the Company has grown and expanded its operations worldwide. In early 1999, the Company acquired control of PetroFina S.A. (hereafter referred to as “PetroFina” or

“Fina”) and, in early 2000, the Company acquired control of Elf Aquitaine S.A. (hereafter referred to as “Elf Aquitaine” or “Elf”). For information concerning the Group’s principal capital expenditures and divestitures, see “Item 4 — B. Business Overview — 5. Investments”, “Item 5 — C. Results 2012-2014” and “Item 5 — D. Liquidity and Capital Resources”.

The Company’s corporate name is TOTAL S.A. Its registered office is 2, place Jean Millier, La Défense 6, 92400 Courbevoie, France. Its telephone number is +33 (0)1 47 44 45 46.

TOTAL S.A. is registered in France at the Nanterre Trade Register under the registration number 542 051 180. The length of the life of the Company is 99 years from March 22, 2000, unless it is dissolved or extended prior to such date.

 

 

 

B. BUSINESS OVERVIEW

 

 

 

TOTAL provides energy-related products and services to customers around the world by discovering, producing and transforming oil and gas, as well as other natural resources (solar and biomass).

The Group’s goal is to be a global, integrated energy company — a leading international oil company and a world-class operator in gas, petrochemicals, solar energy and, tomorrow, biomass. To realize this goal, TOTAL leverages its integrated business model, which enables it to capture synergies between the different business segments of the Group. Together, TOTAL’s commitments to ethical practices, safety and corporate social responsibility form a shared foundation allowing the achievement of four strategic objectives:

 

 

driving profitable, sustainable growth in exploration and production;

 

developing competitive, top-tier refining and petrochemical complexes;

 

responding to customer needs by delivering innovative solutions; and

 

consolidating the Group’s leadership in solar energy and continuing to explore biomass, in order to offer the most appropriate energy solutions.

At the core of TOTAL’s strategy is a strong belief that energy is vital, drives progress and must be made available to everyone. Energy is a precious resource that must be used wisely.

The Group is helping to produce the growing amount of energy that people around the planet need to live and thrive, while ensuring that its operations consistently deliver economic, social and environmental benefits. TOTAL is meeting this challenge with and for its fellow employees, its stakeholders and the local communities, in ways that exceed what is generally expected.

Respect, responsibility and exemplary behavior are the values that underpin TOTAL’s Code of Conduct. It is through strict adherence to these core values and fundamental principles that TOTAL will be able to build strong and sustainable growth for the Group and its stakeholders.

 

 

 

(1) 

Based on market capitalization (in dollars) as of December 31, 2014.

 

2014 Form 20-F TOTAL S.A.   9


Table of Contents

Item 4 - B.1. Geographic Breakdown of Activities

1. GEOGRAPHIC BREAKDOWN OF ACTIVITIES

 

 

 

TOTAL’s worldwide operations in 2014 were conducted through three business segments: Upstream, Refining & Chemicals and Marketing & Services. The table below gives information on the

geographic breakdown of TOTAL’s activities and is taken from Note 5 to the Consolidated Financial Statements included elsewhere herein.

 

 

(M$)    France      Rest of
Europe
     North
America
     Africa      Rest of
world
     Total  

2014

                 

Non-Group sales

     51,471         114,747         23,766         23,281         22,857         236,122   

Property, plant and equipment, intangible assets, net

     4,350         25,137         16,064         41,405         34,602         121,558   

Capital expenditures

     1,266         5,880         3,658         9,798         9,907         30,509   

2013

                 

Non-Group sales

     57,650         128,661         22,332         23,146         19,936         251,725   

Property, plant and equipment, intangible assets, net

     6,251         26,840         19,588         37,847         32,349         122,875   

Capital expenditures

     1,772         6,289         4,157         10,705         11,508         34,431   

2012

                 

Non-Group sales

     59,077         133,439         22,675         23,025         18,821         257,037   

Property, plant and equipment, intangible assets, net

     6,017         23,349         20,082         32,983         26,011         108,442   

Capital expenditures

     2,041         5,660         4,045         9,346         8,383         29,475   

 

2. UPSTREAM SEGMENT

 

 

TOTAL’s Upstream segment includes the activities of Exploration & Production and Gas & Power(1). The Group has exploration and production activities in more than fifty countries and produces oil or gas in approximately thirty countries. Gas & Power conducts activities downstream from production related to natural gas, liquefied natural gas (LNG) and liquefied petroleum gas (LPG), as well as power generation and trading, and other activities.

 

2.1. Exploration & Production

 

 

2.1.1. Exploration and development

TOTAL’s Exploration & Production activities aim at continuing to combine long-term growth and profitability at the level of the best actors of the industry.

TOTAL evaluates exploration opportunities based on a variety of geological, technical, political, economic (including taxes and license terms), environmental and societal factors and on projected oil and gas prices. Discoveries of new fields and extensions of existing fields have brought an additional 2,446 Mboe to the Upstream segment’s proved reserves during the 3-year period ended December 31, 2014 (before deducting production and sales of reserves in place and adding any acquisitions of reserves in place during this period). The net level of revisions during this 3-year period is +181 Mboe, which was due to the overall positive revisions in field behaviors partially offset by the negative impacts of the increase of bitumen price in Canada (from $50.4/b in 2013 to $60.3/b in 2014 for Synbit), the increase in U.S. onshore gas price (from 2011 ($4.21/MBtu) to 2012 ($2.85/MBtu) for Henry Hub) and a perimeter change in two projects.

In 2014, the exploration investments of consolidated subsidiaries amounted to $2,608 million (excluding exploration bonuses), primarily in Angola, Brazil, Norway, South Africa, Iraq, Malaysia, Côte d’Ivoire, Indonesia and Libya. Exploration investments of consolidated subsidiaries amounted to $2,926 million in 2013 and $2,701 million in 2012. For 2015, the exploration budget has been reduced to $1.9 billion to reflect the new market environment.

The Group’s consolidated Exploration & Production subsidiaries’ organic(2) investments amounted to $23 billion in 2014, primarily in Angola, Norway, Australia, Canada, Nigeria, the Republic of the Congo, Russia, the United Kingdom, Indonesia, Gabon, the United

States and Kazakhstan. The Group’s consolidated Exploration & Production subsidiaries’ organic investments amounted to $24 billion in 2013 and $20 billion in 2012.

 

2.1.2. Reserves

The definitions used for proved, proved developed and proved undeveloped oil and gas reserves are in accordance with the United States Securities & Exchange Commission (SEC) Rule 4-10 of Regulation S-X as amended by the SEC Modernization of Oil and Gas Reporting release issued on December 31, 2008. Proved reserves are estimated using geological and engineering data to determine with reasonable certainty whether the crude oil or natural gas in known reservoirs is recoverable under existing regulatory, economic and operating conditions.

TOTAL’s oil and gas reserves are consolidated annually, taking into account, among other factors, levels of production, field reassessments, additional reserves from discoveries and acquisitions, disposal of reserves and other economic factors.

Unless otherwise indicated, any reference to TOTAL’s proved reserves, proved developed reserves, proved undeveloped reserves and production reflects the Group’s entire share of such reserves or such production. TOTAL’s worldwide proved reserves include the proved reserves of its consolidated subsidiaries as well as its proportionate share of the proved reserves of equity affiliates.

For further information concerning changes in TOTAL’s proved reserves for the years ended December 31, 2014, 2013 and 2012, refer to “Supplemental Oil and Gas Information (Unaudited)”.

The reserves estimation process involves making subjective judgments. Consequently, estimates of reserves are not exact measurements and are subject to revision under well-established control procedures.

 

 

10   TOTAL S.A. Form 20-F 2014

 

(1) 

Effective July 1, 2012, the Upstream segment no longer includes the activities of New Energies, which are now reported with Marketing & Services. As a result, certain information has been restated according to the new organization.

(2)

For Exploration & Production, organic investments include exploration investments, net development investments and net financial investments.


Table of Contents

Item 4 - B.2. Upstream Segment

The reserves booking process requires, among other things:

 

 

internal peer reviews of technical evaluations to ensure that the SEC definitions and guidance are followed; and

 

that management makes significant funding commitments towards the development of the reserves prior to booking.

For further information regarding the preparation of reserves estimates, see “Supplemental Oil and Gas Information (Unaudited)”.

 

2.1.3. Proved reserves for years 2014, 2013 and 2012

In accordance with the amended Rule 4-10 of Regulation S-X, proved reserves at December 31 are calculated using a 12-month average price determined as the unweighted arithmetic average of the first-day-of-the-month price for each month of the relevant year unless prices are defined by contractual arrangements, excluding escalations based upon future conditions. The reference prices for 2014, 2013 and 2012 were, respectively, $101.27/b, $108.02/b and $111.13/b for Brent crude.

As of December 31, 2014, TOTAL’s combined proved reserves of oil and gas were 11,523 Mboe (50% of which were proved developed reserves). Liquids (crude oil, condensates, natural gas liquids and bitumen) represented approximately 46% of these reserves and natural gas the remaining 54%. These reserves were located in Europe (mainly in Norway and the United Kingdom), in Africa (mainly in Angola, Gabon, Nigeria and the Republic of the Congo), in the Americas (mainly in Canada, Argentina, the United States and Venezuela), in the Middle East (mainly in Qatar, the United Arab Emirates and Yemen), and in Asia (mainly in Australia, Kazakhstan and Russia).

As of December 31, 2013, TOTAL’s combined proved reserves of oil and gas were 11,526 Mboe (49% of which were proved developed reserves). Liquids (crude oil, condensates, natural gas liquids and bitumen) represented approximately 47% of these reserves and natural gas the remaining 53%.

As of December 31, 2012, TOTAL’s combined proved reserves of oil and gas were 11,368 Mboe (51% of which were proved developed reserves). Liquids (crude oil, condensates, natural gas liquids and bitumen) represented approximately 50% of these reserves and natural gas the remaining 50%.

 

2.1.4. Sensitivity to oil and gas prices

Changes in the price used as a reference for the proved reserves estimation result in non-proportionate inverse changes in proved reserves associated with production sharing and risked service contracts (which together represent approximately 21% of TOTAL’s reserves as of December 31, 2014). Under such contracts, TOTAL is entitled to a portion of the production, the sale of which is meant to cover expenses incurred by the Group. As oil prices increase, fewer barrels are necessary to cover the same amount of expenses. Moreover, the number of barrels recoverable under these contracts may vary according to criteria such as cumulative production, the rate of return on investment or the income-cumulative expenses ratio. This decrease is partly offset by an extension of the duration over which fields can be produced economically. However, the increase in reserves due to extended field life resulting from higher prices is generally less than the decrease in reserves under production sharing or risked service contracts due to such higher prices. As a result, higher prices usually lead to a decrease in TOTAL’s reserves.

Furthermore, changes in the reference price per barrel used for the proved reserves estimation have an impact on the volume of royalties in Canada and thus TOTAL’s share of proved reserves.

Lastly, for any type of contract, a significant decrease of the reference price of petroleum products may involve a reduction of proved reserves.

 

2.1.5. Production

For the full year 2014, average daily oil and gas production was 2,146 kboe/d compared to 2,299 kboe/d in 2013 and 2,300 kboe/d in 2012. Liquids accounted for approximately 48% and natural gas for approximately 52% of TOTAL’s combined liquids and natural gas production in 2014.

The tables on the next pages set forth by geographic area TOTAL’s annual and average daily production of liquids and natural gas for each of the last three years.

Consistent with industry practice, TOTAL often holds a percentage interest in its fields rather than a 100% interest, with the balance being held by joint venture partners (which may include other international oil companies, state-owned oil companies or government entities). TOTAL’s entities frequently act as operator (the party responsible for technical production) on acreage in which it holds an interest. See the table “Presentation of production activities by geographic area” on the following pages for a description of TOTAL’s producing assets.

As in 2013 and 2012, substantially all of the liquids production from TOTAL’s Upstream segment in 2014 was marketed by the Trading & Shipping division of TOTAL’s Refining & Chemicals segment (see the table “Trading’s crude oil sales and supply and refined products sales” in “— 3.2.1. Trading & Shipping”, below).

The majority of TOTAL’s natural gas production is sold under long-term contracts. However, its North American production, and part of its production from the United Kingdom, Norway and Argentina, is sold on the spot market. The long-term contracts under which TOTAL sells its natural gas usually provide for a price related to, among other factors, average crude oil and other petroleum product prices, as well as, in some cases, a cost-of-living index. Though the price of natural gas tends to fluctuate in line with crude oil prices, a slight delay may occur before changes in crude oil prices are reflected in long-term natural gas prices. Due to the interaction between the contract price of natural gas and crude oil prices, contract prices are not usually affected by short-term market fluctuations in the spot price of natural gas.

Some of TOTAL’s long-term contracts, notably in Indonesia, Nigeria, Norway, Qatar, Thailand and Yemen, specify the delivery of quantities of natural gas that may or may not be fixed and determinable. Such delivery commitments vary substantially, both in duration and in scope, from contract to contract throughout the world. For example, in some cases, contracts require delivery of natural gas on an as-needed basis, and, in other cases, contracts call for the delivery of varied amounts of natural gas over different periods of time. Nevertheless, TOTAL estimates the fixed and determinable quantity of gas to be delivered over the period 2015-2017 to be 3,782 Bcf. The Group expects to satisfy most of these obligations through the production of its proved reserves of natural gas, with, if needed, additional sourcing from spot market purchases (refer to “Supplemental Oil and Gas Information (Unaudited)”).

 

 

2014 Form 20-F TOTAL S.A.   11


Table of Contents

Item 4 - B.2. Upstream Segment

2.1.6. Production by region

The following table sets forth the Group’s annual liquids and natural gas production by region.

 

      2014      2013      2012  
      Liquids
Mb
     Natural
gas
Bcf
(b)
     Total
Mboe
     Liquids
Mb
     Natural
gas
Bcf
(b)
     Total
Mboe
     Liquids
Mb
     Natural
gas
Bcf
(b)
     Total
Mboe
 

Africa

     191         253         240         194         255         245         210         257         260   

Algeria

     2         29         7         2         30         8         2         33         8   

Angola

     70         20         73         64         23         68         63         16         65   

Gabon

     20         5         21         20         6         22         20         7         21   

Libya

     10                 10         18                 18         23                 23   

Nigeria

     57         187         94         58         187         95         63         190         102   

The Congo, Republic of

     32         13         35         32         10         34         39         11         41   

North America

     14         104         33         10         93         27         9         90         25   

Canada(a)

     4                 4         5                 5         4                 4   

United States

     10         104         28         5         93         22         5         90         21   

South America

     18         219         57         20         229         61         22         249         66   

Argentina

     3         134         27         5         134         28         4         144         30   

Bolivia

     1         51         11         1         47         10         1         45         10   

Colombia

                                                     0         8         2   

Trinidad & Tobago

                             1         19         4         1         26         6   

Venezuela

     14         34         19         13         29         18         14         26         18   

Asia-Pacific

     11         430         87         11         427         86         10         397         81   

Australia

             8         1                 9         1                 11         2   

Brunei

     1         24         5         1         22         5         1         20         4   

China

             23         4                 17         3                 3         0   

Indonesia

     7         217         47         6         221         48         6         221         48   

Myanmar

             49         6                 47         6                 46         6   

Thailand

     4         108         22         4         112         23         3         97         20   

CIS

     13         414         91         12         382         83         10         332         71   

Azerbaijan

     1         22         5         2         30         7         1         23         6   

Russia

     12         393         86         10         352         76         8         308         65   

Europe

     60         397         133         61         449         143         72         460         156   

France

             3         1         0         16         3         1         21         5   

The Netherlands

     0         62         11         0         71         13         0         67         12   

Norway

     49         210         88         50         210         89         58         227         100   

United Kingdom

     11         122         32         11         152         38         13         144         39   

Middle East

     70         396         143         118         422         196         114         361         180   

United Arab Emirates

     42         22         46         90         26         95         85         26         90   

Iraq

     4         0         4         3         0         3         2                 2   

Oman

     9         22         13         9         24         14         9         22         14   

Qatar

     12         203         48         13         204         50         14         204         51   

Yemen

     3         148         31         4         168         35         4         109         24   

Total production

     377         2,213         783         426         2,257         839         445         2,146         840   

Including share of equity affiliates

     73         726         208         119         714         251         112         597         223   

Angola

             4         1                 6         1                           

Venezuela

     14         2         14         13         3         14         14         3         15   

United Arab Emirates

     40         19         43         88         22         92         82         22         87   

Oman

     8         22         12         8         24         13         8         22         12   

Qatar

     3         139         28         3         141         28         3         133         27   

Yemen

             147         27                 167         31                 109         20   

Russia

     9         392         83         7         351         72         5         308         62   

 

(a) 

The Group’s production in Canada consists of bitumen only. All of the Group’s bitumen production is in Canada.

(b) 

Including fuel gas (155 Bcf in 2014, 151 Bcf in 2013, 144 Bcf in 2012).

 

12   TOTAL S.A. Form 20-F 2014


Table of Contents

Item 4 - B.2. Upstream Segment

The following table sets forth the Group’s average daily liquids and natural gas production by region.

 

      2014      2013      2012  
      Liquids
kb/d
     Natural
gas
Mcf/d
(b)
     Total
kboe/d
     Liquids
kb/d
     Natural
gas
Mcf/d
(b)
     Total
kboe/d
     Liquids
kb/d
     Natural
gas
Mcf/d
(b)
     Total
kboe/d
 

Africa

     522         693         657         531         699         670         574         705         713   

Algeria

     5         79         20         5         82         21         6         90         23   

Angola

     191         54         200         175         62         186         172         44         179   

Gabon

     55         14         58         55         16         59         54         19         57   

Libya

     27                 27         50                 50         62                 62   

Nigeria

     156         511         257         158         511         261         173         521         279   

The Congo, Republic of

     88         35         95         88         28         93         107         31         113   

North America

     39         285         90         28         256         73         25         246         69   

Canada(a)

     12                 12         13                 13         12                 12   

United States

     27         285         78         15         256         60         13         246         57   

South America

     50         599         157         54         627         166         59         682         182   

Argentina

     9         367         75         13         366         78         12         394         83   

Bolivia

     4         139         30         4         129         28         3         124         27   

Colombia

                                                     1         23         6   

Trinidad & Tobago

                             2         52         12         4         70         16   

Venezuela

     37         93         52         35         80         48         39         71         50   

Asia-Pacific

     30         1,178         238         30         1,170         235         27         1,089         221   

Australia

             23         4                 25         4                 29         5   

Brunei

     2         66         15         2         59         13         2         54         12   

China

             63         12                 46         8                 7         1   

Indonesia

     18         594         130         17         605         131         16         605         132   

Myanmar

             135         17                 129         16                 127         16   

Thailand

     10         297         60         11         306         63         9         267         55   

CIS

     36         1,135         249         32         1,046         227         27         909         195   

Azerbaijan

     3         59         14         5         82         20         4         64         16   

Russia

     33         1,076         235         27         964         207         23         845         179   

Europe

     165         1,089         364         168         1,231         392         197         1,259         427   

France

             9         2         1         45         9         2         58         13   

The Netherlands

     1         171         31         1         195         35         1         184         33   

Norway

     135         576         242         136         575         243         159         622         275   

United Kingdom

     29         333         89         30         416         105         35         395         106   

Middle East

     192         1,084         391         324         1,155         536         311         990         493   

United Arab Emirates

     115         61         127         247         71         260         233         70         246   

Iraq

     12         1         12         7         1         7         6                 6   

Oman

     24         61         36         24         66         37         24         61         37   

Qatar

     32         555         132         36         558         137         38         560         139   

Yemen

     9         406         84         10         459         95         10         299         65   

Total production

     1,034         6,063         2,146         1,167         6,184         2,299         1,220         5,880         2,300   

Including share of equity affiliates

     200         1,988         571         325         1,955         687         308         1,635         611   

Angola

             10         2                 16         3                           

Venezuela

     37         6         38         35         7         37         38         7         40   

United Arab Emirates

     109         51         118         240         61         253         225         61         237   

Oman

     23         61         34         23         66         35         23         60         34   

Qatar

     7         381         77         8         385         78         7         364         74   

Yemen

             404         75                 458         84                 299         55   

Russia

     24         1,075         227         19         962         197         15         844         171   

 

(a) 

The Group’s production in Canada consists of bitumen only. All of the Group’s bitumen production is in Canada.

(b) 

Including fuel gas (426 Mcf/d in 2014, 415 Mcf/d in 2013, 394 Mcf/d in 2012).

 

2014 Form 20-F TOTAL S.A.   13


Table of Contents

Item 4 - B.2. Upstream Segment

2.1.7. Presentation of production activities by region

The table below sets forth, by country, the producing assets of the Group’s entities, the year in which the activities commenced, the interest held in each asset and whether a Group entity is operator of the asset.

 

TOTAL’s producing assets as of December 31, 2014(a)      
      Year of
entry into
the country
  

Operated

(Group share in %)

  

Non-operated

(Group share in %)

Africa

              

Algeria

   1952         Tin Fouye Tabankort (35.00%)

Angola

   1953    Girassol, Jasmim, Rosa, Dalia, Pazflor, CLOV (Block 17) (40.00%)    Cabinda Block 0 (10.00%)
              

Kuito, BBLT, Tombua-Landana

(Block 14) (20.00%)(b)

Angola LNG (13.60%)

Gabon

   1928   

Anguille (100.00%)

Anguille Nord-Est (100.00%)

Anguille Sud-Est (100.00%)

Atora (40.00%)

Avocette (57.50%)

Ayol Marine (100.00%)

Baliste (50.00%)

Barbier (100.00%)

Baudroie Marine (50.00%)

Baudroie Nord Marine (50.00%)

Coucal (57.50%)

Girelle (100.00%)

Gonelle (100.00%)

Grand Anguille Marine (100.00%)

Grondin (100.00%)

Hylia Marine (75.00%)

Lopez Nord (100.00%)

Mandaros (100.00%)

M’Boukou (57.50%)

M’Boumba (100.00%)

Mérou Sardine Sud (50.00%)

Pageau (100.00%)

Port Gentil Océan (100.00%)

Port Gentil Sud Marine (100.00%)

Tchengue (100.00%)

Torpille (100.00%)

Torpille Nord Est (100.00%)

  
               Rabi Kounga (47.50%)

Libya

   1959        

zones 15, 16 & 32 (75.00%)(c)

zones 70 & 87 (75.00%)(c)

zones 129 & 130 (30.00%)(c)

zones 130 & 131 (24.00%)(c)

Nigeria

   1962   

OML 58 (40.00%)

OML 99 Amenam-Kpono (30.40%)

OML 100 (40.00%)

OML 102 (40.00%)

   OML 102-Ekanga (40.00%)
      OML 130 (24.00%)   
              

Shell Petroleum Development Company (SPDC 10.00%)

OML 118-Bonga (12.50%)

OML 138 (20.00%)

 

14   TOTAL S.A. Form 20-F 2014


Table of Contents

Item 4 - B.2. Upstream Segment

TOTAL’s producing assets as of December 31, 2014(a)      
      Year of
entry into
the country
  

Operated

(Group share in %)

  

Non-operated

(Group share in %)

The Congo, Republic of

   1968   

Kombi-Likalala-Libondo (65.00%)

Moho Bilondo (53.50%)

Nkossa (53.50%)

Nsoko (53.50%)

Sendji (55.25%)

Tchendo (65.00%)

Tchibeli-Litanzi-Loussima (65.00%)

Tchibouela (65.00%)

  
      Yanga (55.25%)   
              

Loango (42.50%)

Zatchi (29.75%)

North America

        

Canada

   1999         Surmont (50.00%)

United States

   1957         Several assets in the Barnett Shale area (25.00%)(d)
Several assets in the Utica Shale area (25.00%)(d)
Chinook (33.33%)
Tahiti (17.00%)

South America

        

Argentina

   1978   

Aguada Pichana (27.27%)

Aguada San Roque (24.71%)

Aries (37.50%)

Cañadon Alfa Complex (37.50%)

Carina (37.50%)

Hidra (37.50%)

Kaus (37.50%)

    
              

Sierra Chata (2.51%)

Bolivia

   1995        

San Alberto (15.00%) San Antonio (15.00%)

Itaú (41.00%)

Venezuela

   1980         PetroCedeño (30.32%) Yucal Placer (69.50%)

Asia-Pacific

        

Australia

   2005         Various fields in UJV GLNG (27.50%)(e)

Brunei

   1986    Maharaja Lela Jamalulalam (37.50%)     

China

   2006         South Sulige (49.00%)

Indonesia

   1968   

Bekapai (50.00%)

Handil (50.00%)

Peciko (50.00%)

Sisi-Nubi (47.90%)

South Mahakam (50.00%)

Tambora (50.00%)

Tunu (50.00%)

  
              

Badak (1.05%)

Nilam-gas and condensates (9.29%) Nilam-oil (10.58%)

Ruby-gas and condensates (15.00%)

Myanmar

   1992    Yadana (31.24%)     

Thailand

   1990         Bongkot (33.33%)

Commonwealth of Independant States

  

Kazakhstan

   1992         Kashagan (16.81%)

Russia

   1991    Kharyaga (40.00%)   
               Several fields through the participation in OAO Novatek (18.24%)

 

2014 Form 20-F TOTAL S.A.   15


Table of Contents

Item 4 - B.2. Upstream Segment

      Year of
entry into
the country
  

Operated

(Group share in %)

  

Non-operated

(Group share in %)

Europe

        

Norway

   1965   

Atla (40.00%)

Skirne (40.00%)

    
              

Åsgard (7.68%)

Ekofisk (39.90%)

Ekofisk South (39.90%)

Eldfisk (39.90%)

Embla (39.90%)

Gimle (4.90%)

Gungne (10.00%)

Heimdal (16.76%)

Huldra (24.33%)

Islay (5.51%)(f)

Kristin (6.00%)

Kvitebjørn (5.00%)

Mikkel (7.65%)

Oseberg (14.70%)

Oseberg East (14.70%)

Oseberg South (14.70%)

Sleipner East (10.00%)

Sleipner West (9.41%)

Snøhvit (18.40%)

Stjerne (14.70%)

Tor (48.20%)

Troll I (3.69%)

Troll II (3.69%)

Tune (10.00%)

Tyrihans (23.15%)

Visund (7.70%)

Visund South (7.70%)

Visund North (7.70%)

The Netherlands

   1964   

F6a gas (55.66%)

F6a oil (65.68%)

F15a Jurassic (38.20%)

F15a/F15d Triassic (32.47%)

F15d (32.47%)

J3a (30.00%)

K1a (40.10%)

K1b/K2a (60.00%)

K2c (60.00%)

K3b (56.16%)

K3d (56.16%)

K4a (50.00%)

K4b/K5a (36.31%)

K5b (50.00%)

K6/L7 (56.16%)

L1a (60.00%)

L1d (60.00%)

L1e (55.66%)

L1f (55.66%)

L4a (55.66%)

L4d (55.66%)

  
              

E16a (16.92%)

E17a/E17b (14.10%)

J3b/J6 (25.00%)

K9ab-A (22.46%)

Q16a (6.49%)

United Kingdom

   1962   

Alwyn North, Dunbar, Ellon, Forvie North, Grant, Jura, Nuggets (100.00%) Elgin-Franklin, West Franklin (46.17%) Glenelg (58.73%)

Islay (94.49%)(f)

  
              

Bruce (43.25%)

Markham unitized field (7.35%)

Keith (25.00%)

 

16   TOTAL S.A. Form 20-F 2014


Table of Contents

Item 4 - B.2. Upstream Segment

      Year of
entry into
the country
  

Operated

(Group share in %)

  

Non-operated

(Group share in %)

Middle East

              

U.A.E.

   1939    Abu Dhabi-Abu Al Bu Khoosh (75.00%)   
              

Abu Dhabi offshore (13.33%)(g)

GASCO (15.00%)

ADGAS (5.00%)

Iraq

   1920         Halfaya (22.5%)(h)

Oman

   1937        

Various fields onshore (Block 6) (4.00%)(i)

Mukhaizna field (Block 53) (2.00%)(j)

Qatar

   1936    Al Khalij (100.00%)   
              

North Field-Bloc NF Dolphin (24.50%)

North Field-Bloc NFB (20.00%)

North Field-Qatargas 2 Train 5 (16.70%)

Yemen

   1987    Kharir/Atuf (Block 10) (28.57%)   
               Yemen LNG (39.62%) Various fields onshore (Block 5) (15.00%)

 

(a) 

The Group’s interest in the local entity is approximately 100% in all cases except for Total Gabon (58.28%), Total E&P Congo (85.00%) and certain entities in Abu Dhabi and Oman (see notes b through i below).

(b) 

Stake in the company Angola Block 14 BV (TOTAL 50.01%).

(c) 

TOTAL’s stake in the foreign consortium.

(d) 

TOTAL’s interest in the joint venture with Chesapeake.

(e) 

TOTAL’s interest in uncorporated joint venture.

(f) 

The field of Islay extends partially in Norway. TOTAL E&P UK holds a 94.49 % and TOTAL E&P Norge 5.51%

(g) 

Through ADMA (equity affiliate), TOTAL has a 13.33% interest in the operating company, Abu Dhabi Marine Operating Company.

(h) 

TOTAL holds an interest of 22.5% in the consortium.

(i) 

TOTAL holds an indirect interest of 4.00% in Petroleum Development Oman LLC, operator of Block 6, via its 10% interest in Private Oil Holdings Oman Ltd. TOTAL also has a 5.54% interest in the Oman LNG facility (trains 1 and 2), and an indirect participation of 2.04% through OLNG in Qalhat LNG (train 3).

(j) 

TOTAL holds a direct interest of 2.00% in Block 53.

 

2.1.7.1. Africa

In 2014, TOTAL’s production in Africa was 657 kboe/d, representing 31% of the Group’s overall production, compared with 670 kboe/d in 2013 and 713 kboe/d in 2012.

In South Africa, TOTAL acquired an interest in the 11B-12B license (50%, operator) in September 2013. This license, which covers an area of 19,000 km2, is located approximately 175 km south of the South African coast in water depths ranging from 200 m to 1,800 m. The drilling of an exploration well, which began in July 2014 and stopped at the beginning of October 2014, should resume when all of the conditions permit.

In addition, the Group holds a technical cooperation license for the Outeniqua Block (100%), which covers approximately 76,000 km2 and is located to the southwest of the 11B-12B license in water depths ranging from 400 m to 4,000 m.

In Algeria, TOTAL’s production was 20 kboe/d during 2014, compared with 21 kboe/d in 2013 and 23 kboe/d in 2012. All of the Group’s production in Algeria comes from the Tin Fouyé Tabankort (TFT) field (35%). TOTAL also has a 37.75% stake in the Timimoun gas development project.

 

 

The development of the Timimoun field continued in 2014. The plant construction contract was signed in February 2014 and the drilling rig contract in September 2014.

 

TOTAL decided not to implement the Ahnet project and abandoned the Ain Enakhal exploration well.

In Angola, the Group’s production in 2014 was 200 kboe/d, compared with 186 kboe/d in 2013 and 179 kboe/d in 2012. This production comes primarily from Blocks 0, 14 and 17. Recent highlights include the start-up of production on the Pazflor project in 2011 and the CLOV project in 2014, as well as the acquisition of

interests in the exploration blocks 25, 39 and 40 in the Kwanza basin.

 

 

Deep offshore Block 17 (40%, operator) is TOTAL’s principal asset in Angola. It is composed of four major producing hubs: Girassol, Dalia, Pazflor and CLOV. CLOV, the newest hub, was launched in 2010, started production in June 2014 and reached its plateau production of 160 kboe/d in September 2014.

 

On the ultra-deep offshore Block 32 (30%, operator), the Kaombo project was launched in April 2014 to develop the discoveries in the southeast part of the block via two FPSOs (Floating Production Storage and Offloading facilities) with a capacity of 115 kb/d each. Production start-up is planned for 2017. The exploration and delineation of the center and north parts of the block is ongoing.

 

On Block 14 (20%(1)), production comes from the Tombua-Landana and Kuito fields as well as the BBLT project, comprising the Benguela, Belize, Lobito and Tomboco fields.

 

Block 14K (36.75%) is the offshore unitization zone between Angola (Block 14) and the Republic of the Congo (Haute Mer license). Launched in 2012, the development of the Lianzi field will be via a connection to the existing BBLT platform (Block 14). TOTAL’s interest in the unitized block is held 10% through Angola Block 14 BV and 26.75% through Total E&P Congo.

 

On Block 0 (10%), the development of Mafumeira Sul was approved by the partners and the authorities in 2012. This project constitutes the second development phase of the Mafumeira field.

 

In April 2014, TOTAL sold its entire stake in Block 15/06 (15%).

 

 

 

(1) 

Interest held by the company Angola Block 14 BV (TOTAL 50.01%, INPEX Corporation 49.99% since February 2013).

 

2014 Form 20-F TOTAL S.A.   17


Table of Contents

Item 4 - B.2. Upstream Segment

TOTAL has interests in exploration blocks 17/06 (30%, operator) in the Lower-Congo basin and blocks 25 (35%, operator), 39 (15%) and 40 (40%, operator) in the deep offshore Kwanza basin. In 2014 and early 2015, the Group drilled pre-salt targets on blocks 25, 39 and 40. TOTAL relinquished its interest in Block 33 (58.67%, operator) in November 2014.

TOTAL is also developing its LNG activities through the Angola LNG project (13.6%), which includes a gas liquefaction plant near Soyo supplied in particular by the gas associated with production from Blocks 0, 14, 15, 17 and 18. LNG production started in June 2013 but various technical incidents required the extended shut down of the plant.

In Côte d’Ivoire, TOTAL is active in four deep offshore exploration licenses located 50 km to 100 km from the coast and covering approximately 5,200 km2 at water depths ranging from 1,000 m to 3,000 m.

On the CI-100 license (60%, operator) located in the Tano basin, an initial exploration well (Ivoire-1X) was drilled in early 2013 at a water depth of more than 2,300 meters.

On the licenses CI-514 (54%, operator), CI-515 (45%) and CI-516 (45%) situated in the San Pedro basin, a 3D seismic survey was carried out in 2012 and three exploration wells were drilled in 2014.

In Egypt, TOTAL relinquished Block 4 (East El Burullus Offshore; 50% operator) at the end of the first exploration period in August 2014 after having drilled the Kala-1 well in 2013.

In September 2014, Total was awarded Block 2 (North El Mahala Onshore) located in the Nile delta.

In Gabon, the Group’s production in 2014 was 58 kboe/d compared with 59 kboe/d in 2013 and 57 kboe/d in 2012. The Group’s exploration and production activities in Gabon are mainly carried out by Total Gabon(1).

 

 

As part of the redevelopment project (estimated production capacity 20 kboe/d) of the Anguille field (100%, operator), the AGM North platform was installed in 2012. Production from the platform started in 2013 and fourteen wells are now operational.

 

In the Torpille field (100%, operator), a 3D seismic survey is underway.

 

On the deep offshore Diaba license (42.5%, operator), an initial exploration well (Diaman-1B) was drilled in 2013 at a water depth of more than 1,700 m. This well revealed an accumulation of gas and condensates. A 3D seismic survey was acquired in the western part of the block in the fourth quarter of 2014.

 

The Nguongui-updip well drilled on the Mutamba-Iroru license (50%) in 2012 revealed the presence of hydrocarbons.

 

On the Nziembou license (20%), the drilling of the Igongo-1X well revealed a multi-layer accumulation of oil and gas and the drilling of the Monbou 1 prospect was completed in early January 2015.

In Kenya, TOTAL has interests on the offshore L5 and L7 licenses (40%) and the L11a, L11b and L12 licenses (30% after selling 10% of the stake in December 2014) and is the operator of the L22 license (70%) located in the Lamu delta in water depths ranging from 1,000 m to 3,500 m.

In 2013, two exploration wells were drilled in Blocks L7 and L11b.

On the offshore L22 license, seabed core drilling operations were carried out in early 2014 and a 3D seismic survey was carried out, benefitting from synergies with the adjacent blocks.

In Libya, the Group’s production in 2014 was 27 kb/d compared with 50 kb/d in 2013 and 62 kb/d in 2012. TOTAL is a 75%(2) partner in the Mabruk (Blocks 70 and 87) and Al Jurf (Blocks 15, 16 and 32) zones operated by Mabruk Oil Operations, a company held by National Oil Corporation (NOC) and TOTAL. In addition, TOTAL is a partner in the El Sharara zone (which comprises Blocks 129 and Blocks 130 (30%(3)) and 130 and 131 (24%(3))). Finally, TOTAL is the operator of the Block NC191 (100%(3)) exploration block.

The security situation in 2014 led the Group to gradually reduce the number of its personnel in Libya. Beginning in mid-2013 and through to the summer of 2014, production was affected by the blockade of most of the country’s terminals and pipelines.

 

 

In the onshore Blocks 70 and 87 (Mabruk), production has been stopped since August 2013 due to the blockade of the Es Sider export terminal. Production resumed in September 2014 with the reopening of the terminal before being disrupted again mid-December due to the security situation near the Es Sider terminal; the field has not been producing since then.

 

In the onshore Blocks 129, 130 and 131 (El Sharara), production was interrupted several times in 2014. Nevertheless, the exploration of these blocks continued in 2014 with the drilling of three wells.

 

In the offshore Blocks 15, 16 and 32 (Al Jurf), production has not been affected by the social unrest in the country. However, the A1-16/3 exploration well which began drilling at year-end 2013 was plugged and temporarily abandoned in August 2014.

In Madagascar, TOTAL is active on the Bemolanga 3102 license (60%, operator). A two-year extension of the exploration phase was approved by the local authorities in August 2014.

In Morocco, on the 100,000 km2 Anzarane offshore reconnaissance contract which was granted in December 2011 to TOTAL and ONHYM (National Bureau of Petroleum and Mines), an extension was granted until December 2015. The processing and interpretation of a 3D seismic survey, acquired in 2013 in the southern part of the block, is ongoing.

In Mauritania, the Group holds exploration interests in the ultra-deep offshore C9 license (90%, operator) and the onshore Ta29 license (72%, operator) in the Taoudenni basin, both acquired in 2012.

 

 

On Block Ta29, following the results of the 2D seismic survey performed in 2012, studies are underway to assess the block. In 2013, TOTAL sold an 18% stake in Block Ta29, reducing its stake to 72%.

 

A 3D seismic survey campaign covering 4,700 km2 was conducted on Block C9 in 2013.

 

Furthermore, at the end of the exploration period in July 2014, Blocks Ta7 and Ta8 (60%, operator) were relinquished to the authorities.

In Mozambique, TOTAL acquired a 40% stake in the production sharing contract for offshore zones 3 and 6 in 2012. Located in the Rovuma basin, these two blocks cover an area of 15,250 km2 from the coast up to water depths of 2,500 m. Half of the area of the two blocks was relinquished in 2013. A 500 km2 3D seismic survey was carried out between year-end 2014 and beginning of 2015.

 

 

18   TOTAL S.A. Form 20-F 2014

 

(1) 

Total Gabon is a company under Gabonese law listed on Euronext Paris. TOTAL holds 58.28%, the Republic of Gabon holds 25% and the public float is 16.72%.

(2) 

TOTAL’s stake in the foreign consortium.


Table of Contents

Item 4 - B.2. Upstream Segment

In Nigeria, the Group’s production in 2014 was 257 kboe/d compared with 261 kboe/d in 2013 and 279 kboe/d in 2012. This decline was primarily due to the sharp increase in oil bunkering and a blockade of Nigeria LNG’s export cargoes in 2013. Nigeria is the leading contributor to the Group’s production.

TOTAL has been present in Nigeria since 1962 and operates five of the thirty seven oil mining leases (OML) in which it has interests and also holds interests in four oil prospecting licenses (OPL).

Regarding the principal variations in TOTAL’s permits since 2012:

 

 

In September 2013, TOTAL was granted approval by the authorities to increase its stake in OPL 285 from 26.67% to 60%. In May 2013, TOTAL obtained the approval of the authorities for the renewal of OML 99, 100 and 102 for a period of twenty years.

 

On OML 138 (20%), TOTAL started production in the Usan offshore field in 2012, reaching 130 kboe/d in 2013. In 2014, the Ukot South-2B and Ukot South-3 exploration wells led to two oil discoveries. The Group is actively pursuing the sale process launched in November 2012, which was not able to close. TOTAL ceased to be the operator of OML 138 in February 2014.

 

Block 1 (48.6%, operator) of the Joint Development Zone was relinquished in September 2013, and OPL 221 was relinquished in November 2013.

 

In 2012, TOTAL sold its 10% stake in OML 30, 34 and 40, which were operated via the Shell Petroleum Development Company (SPDC) joint venture. Furthermore, new sales processes for four blocks (OML 18, 24, 25 & 29) were launched in early 2014, with the sale of OML 24 finalized in November 2014, and those of OML 18 and OML 29 finalized in March 2015.

TOTAL continues to develop its operated assets, in particular:

 

 

OML 58 (40%, operator): as part of its joint venture with the Nigerian National Petroleum Corporation (NNPC), TOTAL is pursuing a project to increase the block’s gas production capacity from 370 Mcf/d to 550 Mcf/d.

 

OML 102 (40%, operator): TOTAL achieved the flare-out portion of the Ofon Phase 2 project in December 2014. The associated gas from the Ofon field is now being compressed, evacuated to shore and monetized via Nigeria LNG (NLNG).

 

OML 130 (24%, operator): the development of the Egina field (capacity of 200 kboe/d) was launched in June 2013.

 

OML 99 (40%, operator): additional studies are underway for the development of the Ikike field.

TOTAL is also active in the LNG sector with a 15% stake in Nigeria LNG Ltd, which owns a liquefaction plant with a total capacity of 22 Mt/y. On Brass LNG, since the withdrawal of one of the partners, TOTAL’s stake has temporarily increased from 17% to 20.48%. Studies are currently ongoing for a two train liquefaction plant with a 4.5 Mt/y capacity each.

The Group’s non-operated production in Nigeria comes mainly from the SPDC joint venture, in which TOTAL holds a 10% stake. The sharp increase of oil bunkering in 2013, which continued in 2014, had a negative impact on onshore production, as well as on the integrity of the joint venture’s facilities and the local environment.

In addition, TOTAL holds a stake in the deep offshore OML 118 (12.5%), including the Bonga field, which contributed 15 kboe/d to the Group’s production in 2014. On OML 118, a pre-unitization agreement relating to the Bonga South West/Aparo discovery (10%) was signed in December 2013.

In Uganda, where TOTAL has been active since 2012, the Group holds a 33.33% interest in the EA-1, EA-1A and EA-2 licenses as

well as the Kingfisher license, located in the Lake Albert region. TOTAL is the operator of the EA-1 and EA-1A licenses and a partner on the other licenses.

 

 

On the EA-1 license, a campaign of wells, production tests and a 3D seismic survey were carried out between 2012 and mid-2014. As of year-end 2014, five development plans had been submitted to the authorities: Ngiri (submitted in December 2013), Jobi-Rii (submitted in June 2014) and Mpyo, Gunya and Jobi East (submitted in December 2014).

 

The EA-1A license expired in February 2013 following a campaign of five exploration wells that resulted in one discovery (Lyec). With the exception of the area relating to this discovery, the license has been returned to the authorities.

 

On the EA-2 license, a campaign of wells and production tests that began in 2012 was completed in 2014. Two development plans were submitted to the authorities in June 2013 (Kasamene and Wahrindi fields, as well as those of Kigogole, Ngege, Ngara and Nsoga).

 

The development plan for the Kingfisher field, which is located on the EA-3 production license, was approved by the authorities in September 2013.

 

The Kanywataba license expired in 2012 and was returned to the authorities.

In the Republic of the Congo, the Group’s production in 2014 was 95 kboe/d compared with 93 kboe/d in 2013 and 113 kboe/d in 2012. The reduced production in 2013 was due to a planned shutdown on the Nkossa field. The decrease in production between 2012 and 2014 was due primarily to the natural decline of the fields. In December 2013, Qatar Petroleum International Upstream (QPI) purchased a 15% stake in the capital of Total E&P Congo via a share capital increase of the subsidiary.

 

 

The Moho Bilondo offshore field (53.5%, operator) reached plateau production of 90 kboe/d in mid-2010. The Phase 1b (capacity of 40 kboe/d) and Moho North (capacity of 100 kboe/d) project was launched in March 2013, with production start-up planned in 2015 and 2016, respectively.

 

Block 14K (36.75%) corresponds to the offshore unitization zone between the Haute Mer license in the Republic of the Congo and Block 14 in Angola. The development of the Lianzi field was launched in 2012. TOTAL holds a 26.75% interest in the unitized block through Total E&P Congo and a 10% interest through Angola Block 14 BV.

 

In July 2013, TOTAL obtained the Haute Mer B license (34.62%, operator). The authorities approved the license in June 2014.

 

As part of the renewal of the Loango and Zatchi licenses, an agreement on the related contractual and fiscal conditions was signed in October 2013. Following the approval of the authorities in June 2014, TOTAL’s interests in these licenses decreased respectively from 50% to 42.50% for Loango and from 35% to 29.75% for Zatchi, with retroactive effect from October 2013.

In the Lake Albert region of the Democratic Republic of the Congo, the Block III (66.66%, operator) exploration license was granted in 2012 for an initial three-year period. As a result of the security situation in the eastern part of the country in 2012, the license was extended for one year. The prospecting program is limited to the northern portion of the license, which is outside the Virunga park.

In the Republic of South Sudan, TOTAL is negotiating a new contract with the authorities that would enable it to resume exploration activities in part of Block B. Since the independence of the Republic of South Sudan in 2011, TOTAL is no longer present in Sudan.

 

 

2014 Form 20-F TOTAL S.A.   19


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Item 4 - B.2. Upstream Segment

2.1.7.2. North America

In 2014, TOTAL’s production in North America was 90 kboe/d, representing 4% of the Group’s total production, compared with 73 kboe/d in 2013 and 69 kboe/d in 2012.

In Canada, the Group’s production in 2014 was 12 kboe/d compared to 13 kboe/d in 2013 and 12 kboe/d in 2012. The Group’s oil sands portfolio is focused around two themes: Steam Assisted Gravity Drainage (SAGD) on the Surmont (50%) asset, and mining at Fort Hills (39.2%). In addition, the Group holds stakes in a number of other oil sands leases, including Joslyn (38.25%, operator) and Northern Lights (50%, operator).

 

 

On Surmont, in order to optimize production, additional wells were drilled in 2013 and a decision was made to construct an additional steam generation unit.

The second Surmont development phase is under construction (total capacity of phase 1 and 2 estimated at 130 kb/d).

 

The development of the Fort Hills project, with an estimated capacity of 180 kb/d, is underway.

 

On the Joslyn and Nothern Lights assets, a final investment decision is not expected in the near future due to the degraded economic environment.

 

Due to the current economic environment, the Group impaired its oil sands assets in Canada by $2.2 billion in its 2014 consolidated accounts.

 

In 2013, TOTAL finalized the sale of its 49% stake in the Voyageur upgrader project.

In the United States, the Group’s production in 2014 was 78 kboe/d compared with 60 kboe/d in 2013 and 57 kboe/d in 2012.

 

 

In the Gulf of Mexico:

 

   

Phase 2 of the deep offshore Tahiti oil field (17%) was launched in 2010. This phase comprises drilling four injection wells and two production wells.

   

The Chinook 5 well on the deep offshore Chinook project (33.33%) started production in early 2014.

   

The TOTAL (40%) — Cobalt (60%, operator) alliance’s exploration campaign, which was launched in 2009, resumed in 2012 with the Ligurian-2 and North Platte wells, resulting in an oil discovery on the latter. A new drilling campaign commenced in February 2015 with the drilling of the North Platte 2 well.

 

TOTAL is active in shale gas production in Texas via a 25% stake in a joint venture operated by Chesapeake in the Barnett Shale basin. Drilling operations have been sharply reduced since 2012 (approximately 40 wells were drilled in 2014 compared to approximately 60 in 2013 and approximately 100 in 2012).

 

TOTAL is also active in the production of liquids-rich shale gas in the Utica region in Ohio via a joint venture (25%) operated by Chesapeake. Approximately 170 wells were drilled in 2014 (compared to more than 200 wells in 2013 and approximately 100 in 2012) and 207 wells have been connected and have started production (compared with 190 in 2013 and 47 in 2012). In November 2014, TOTAL sold its 25% stake in Cardinal Gas Services LLC, a company providing gas collection and treatment services for Utica.

 

The Group holds a 55.7% stake in American Shale Oil LLC (AMSO), which is developing an in situ shale oil production technology.

 

In 2012, TOTAL entered into a 50/50 joint venture with Red Leaf Resources, which is developing an ex situ shale oil production technology. In the summer of 2014, the joint venture launched a production pilot.

 

Regarding this shale oil theme, TOTAL acquired approximately 120 km2 of additional land in Colorado and Utah in 2012.

In Mexico, TOTAL is conducting various studies with state-owned PEMEX under a general technical cooperation agreement renewed in July 2011 for a period of five years.

 

2.1.7.3. South America

In 2014, TOTAL’s production in South America was 157 kboe/d, representing 7% of the Group’s total production, compared with 166 kboe/d in 2013 and 182 kboe/d in 2012.

In Argentina, where TOTAL has been present since 1978, the Group operated approximately 30%(1) of the country’s gas production in 2014. The Group’s production in 2014 was 75 kboe/d compared with 78 kboe/d in 2013 and 83 kboe/d in 2012. In 2012, the Argentinean government concluded gas price agreements with various producers. Under the terms of these agreements, the Argentinean government guarantees the price of gas for quantities above a fixed production level in exchange for compliance with defined production targets and applicable penalties (i.e., “Deliver or Pay”). In February 2013, TOTAL signed an agreement of this type for a period of five years with retroactive effect from December 1, 2012.

 

 

In Tierra del Fuego, the Group operates the Carina and Aries offshore fields (37.5%). A drilling campaign consisting of two additional wells began in 2014 based on the existing platform. The development of the Vega Pleyade field (37.5%, operator) was launched in October 2013 (production capacity of 350 Mcf/d).

 

In the Neuquén basin, TOTAL started a drilling campaign on its mining licenses in 2011 in order to assess their shale gas and shale oil potential. This campaign, which started on the Aguada Pichana licenses (27.3%, operator), was subsequently extended to all of the blocks. The initial results of the production tests on the wells drilled during this campaign were all positive. Two pilot developments intended to test the unconventional production potential at the Aguada Pichana and Rincón la Ceniza (42.5%, operator) Blocks have been launched.

In Aruba, TOTAL acquired a 35% stake in the offshore Aruba license (14,000 km2) in July 2014. A 3D seismic survey covering 3,250 km2 was carried out.

In Bolivia, the Group’s production, primarily gas, was 30 kboe/d in 2014 compared with 28 kboe/d in 2013 and 27 kboe/d in 2012. TOTAL has stakes in seven licenses: three production licenses, San Alberto and San Antonio (15%) and the Tarija Oeste Block XX (41%); two licenses in the development phase, Aquio and Ipati (60%, operator); and two licenses in the exploration phase, Rio Hondo (50%) and Azero (50%, operator of the exploration phase).

 

 

20   TOTAL S.A. Form 20-F 2014

 

(1) 

Source: Argentinean Ministry of Federal Planning, Public Investment and Services — Energy Secretary.


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Item 4 - B.2. Upstream Segment

 

The second development phase of the Itaú gas and condensates field located on the Tarija Oeste Block XX started production in January 2014 with a production capacity of 176 Mcf/d.

 

Following the discovery of the Incahuasi gas field, located on the Ipati Block, two additional wells were drilled in 2011 and 2013. In April 2013, TOTAL was granted approval by the authorities to start the first development phase of the project, including the connection of three previously drilled wells to a central processing plant with a capacity of 6.5 Mm3/d. An additional well was drilled in 2014 on the Ipati Block. In mid-2014, TOTAL reduced its participation in Aquio and Ipati from 80% to 60%.

 

In 2013, TOTAL acquired a 50% stake in the Azero exploration license in the Andean Piedmont, located west of the Ipati and Aquio Blocks and covering an area of more than 7,800 km2. The exploration period started in June 2014.

In Brazil, the Group has stakes in fourteen exploration licenses.

 

 

In 2013, TOTAL acquired a 20% stake in the Libra field, located in Brazil’s offshore Santos basin, the potential of which is currently being assessed. The field is located in the ultra-deep offshore (2,000 m) approximately 170 km off the coast of Rio de Janeiro and covers an area of 1,550 km2. The drilling of two wells began in the third quarter of 2014 in the field’s northwest and center zones.

 

Following the eleventh bid round organized by the Brazilian authorities in May 2013, TOTAL acquired stakes in ten new exploration licenses. The Group operates five blocks (40%) located in the Foz do Amazonas basin (FZA-M-57, FZA-M-86, FZA-M-88, FZA-M-125 and FZA-M-127) and holds an interest in block CE-M-661 (45%) located in the Ceara basin. TOTAL also holds a 25% stake in three blocks (ES-M-669, ES-M-671 and ES-M-743) located in the Espirito Santo basin and a stake in the BAR-M-346 block (50%) located in the Barreirinhas basin. Seismic survey campaigns were completed in 2014 on the Foz do Amazonas and Espirito Santo basins.

 

TOTAL also holds stakes in the Xerelete field, which the Group has operated since 2012. This field is primarily located on Block BC-2 (41.2%) and extends into Block BM-C-14 (50%). A well targeting both post-salt and pre-salt horizons was drilled and tested in January 2014.

 

On the Gato Do Mato field located in Block BM-S-54 (20%) in the Santos basin, a well was drilled in 2012.

In Colombia, TOTAL has not had any production since the 2012 sale of its TEPMA BV subsidiary, which held a stake in the Cusiana field. Production was 6 kboe/d in 2012.

On the Niscota license (50%), the drilling program commenced in 2009 is ongoing.

In 2013, TOTAL sold its entire share in the Ocensa pipeline while retaining its transport rights. Subsequently, TOTAL signed an agreement in December 2014 to sell part of its transportation rights in the Ocensa pipeline and closing of this transaction occurred in February 2015.

In French Guiana, TOTAL owns a 25% stake in the Guyane Maritime license. This license, located approximately 150 km from the coast in water depths ranging from 200 m to 3,000 m, covers an area of approximately 24,000 km2. At year-end 2011, the authorities extended the exploration license until May 31, 2016.

Further to the discovery of Zaedyus, a drilling campaign was conducted from July 2012 to year-end 2013, but was unable to confirm the extension of a reservoir.

In Trinidad and Tobago, TOTAL sold all of its exploration and production interests in 2013. The Group’s production in 2013 was 12 kboe/d and 16 kboe/d in 2012.

In Uruguay, TOTAL holds a 100% stake in three exploration licenses: offshore Block 14, and onshore Blocks B1 and B2.

 

 

In October 2013, TOTAL signed two exploration and production contracts for Blocks B1 and B2 for unconventional plays. These two blocks, which cover a total area of 5,200 km2, are primarily located in the Artigas province in the northwestern part of the country.

 

In 2012, TOTAL acquired a stake in Block 14, which is located approximately 250 km offshore in water depths ranging from 2,000 m to 3,500 m and covers an area of some 6,700 km2. A 3D seismic acquisition of the entire block was completed in early 2014.

In Venezuela, where TOTAL has had operations since 1980, the Group’s production was 52 kboe/d in 2014 compared with 48 kboe/d in 2013 and 50 kboe/d in 2012. TOTAL has equity stakes in PetroCedeño (30.3%), in Yucal Placer (69.5%) and in the offshore exploration Block 4, located in Plataforma Deltana (49%).

The development phase of the southern zone of PetroCedeño continues (86 producing wells were drilled at year-end 2014 compared with 43 wells at year-end 2013), as well as the debottlenecking project for the water separation and treatment facilities. In 2013, the postponement of an additional debottlenecking project combined with a performance study performed on the field led to a revision of PetroCedeño’s reserves.

Pursuant to an amendment to the gas sale contract, a new development phase of the Yucal Placer field was launched in 2012. The field’s production reached 150 Mcf/d in April 2014 following the commissioning of the first clusters and the debottlenecking of the existing gas treatment train.

 

2.1.7.4. Asia-Pacific

In 2014, TOTAL’s production in Asia-Pacific was 238 kboe/d, representing 11% of the Group’s total production, compared with 235 kboe/d in 2013 and 221 kboe/d in 2012.

In Australia, where TOTAL has held leasehold rights since 2005, the Group’s production was 4 kboe/d in 2014 and in 2013, and 5 kboe/d 2012.

 

 

Following the acquisition of an additional 6% stake in 2013, TOTAL has held a 30% stake in the Ichthys project. Launched in early 2012, the project involves the development of a gas and condensate field in the Browse basin. The development consists of a floating platform designed for gas production, treatment and export, an FPSO (processing capacity of 100 kb/d of condensates) to stabilize and export condensates, an 889 km gas pipeline and an onshore liquefaction plant in Darwin with a capacity of 8.4 Mt/y of LNG and 1.6 Mt/y of LPG (liquefied petroleum gas). The LNG has already been sold mainly to Asian buyers under long-term contracts.

 

GLNG (27.5%) is an integrated gas production, transport and liquefaction project with a capacity of 7.2 Mt/y, based on the development of coal seam gas from the Fairview, Roma, Scotia and Arcadia fields. The upstream development of the project and the liquefaction plant are nearing completion.

 

In 2013, the WA-492 and WA-493 licenses in the Carnarvon basin were awarded to TOTAL (100%, operator). A 2D seismic campaign began in January 2015.

 

 

2014 Form 20-F TOTAL S.A.   21


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Item 4 - B.2. Upstream Segment

 

TOTAL holds a 40% stake in the WA-343-P license.

 

At year-end 2012, TOTAL reduced its share in the WA-408 license located in the Browse basin (50%, operator) by disposing of 50% of its stake. Drilled in the first half of 2013, the first exploration well, Basset-1, revealed hydrocarbons. Completed at year-end 2013, the second exploration well has been definitively abandoned.

 

On the WA-403 license (60%, operator) located in the Bonaparte basin, a well drilled in 2011 indicated the presence of hydrocarbons. A 3D seismic survey was conducted in 2013. The adjacent Block WA-402-P was relinquished in July 2014.

 

In 2012, TOTAL signed an agreement to enter three shale gas exploration licenses in the South Georgina basin in the center of the country. In the second half of 2013, a 2D seismic survey was conducted on these three licenses.

In Brunei, where TOTAL has been present since 1986, the Group operates the offshore Maharaja Lela Jamalulalam gas and condensate field located on Block B (37.5%). The Group’s production in 2014 was 15 kboe/d compared with 13 kboe/d in 2013 and 12 kboe/d in 2012. The gas is delivered to the Brunei LNG liquefaction plant.

In 2013, the study regarding the additional development south of the field (Maharaja Lela South) was completed. The project was officially launched in early 2014 with the signature of most of the contracts and a 20-year extension of the existing license.

Studies are currently being conducted to reassess the potential of the deep offshore exploration Block CA1 (54%, operator), which includes the Jagus East discovery.

In China, TOTAL has been present since 2006 on the South Sulige Block located in the Ordos basin in Inner Mongolia province. Following appraisal work by TOTAL, China National Petroleum Corporation (CNPC) and TOTAL agreed to a development plan pursuant to which CNPC is the operator and TOTAL holds a 49% stake. The authorities approved this development plan in April 2014. After an initial test phase that began in August 2012, the Group’s production in 2014 was 12 kboe/d compared with 8 kboe/d in 2013. The drilling of development wells continues.

In March 2013, TOTAL and Sinopec concluded a joint study agreement relating to shale gas potential on the Xuancheng license (4,000 km2) close to Nanjing. A 2D seismic survey covering 600 km was conducted from October 2013 to February 2014. The drilling of an initial exploration well started in late 2014.

In Indonesia, where TOTAL has had operations since 1968, the Group’s production was 130 kboe/d in 2014 compared with 131 kboe/d in 2013 and 132 kboe/d in 2012.

TOTAL’s operations in Indonesia are primarily concentrated on the Mahakam license (50%, operator), which covers in particular the Peciko and Tunu gas fields. TOTAL also has a stake in the Sisi-Nubi gas field (47.9%, operator). The Group delivers most of its natural gas production to the Bontang LNG plant. These volumes of gas accounted for approximately 80% of Bontang’s LNG supply in 2014. This gas production is supplemented by condensate and oil production from the Handil and Bekapai fields, which are operated by the Group.

 

 

With regard to the Mahakam license:

   

Tunu: in 2014, additional development wells were drilled in the main reservoir as well as in the shallow gas reservoirs;

   

Peciko: phase 7 drilling operations continue;

   

South Mahakam: production started in 2012 and development drilling operations continued. Phase 3 of the project, which includes the development of the Jempang and Metulang fields, is currently underway; and

   

Sisi-Nubi: drilling operations are continuing within the framework of a second phase of development. The gas from Sisi-Nubi is produced through Tunu’s processing facilities.

 

On the Sebuku license (15%), production started at the Ruby gas field in October 2013 with a capacity of approximately 100 Mcf/d. Ruby’s production is transported by pipeline for processing and separation at the Senipah terminal operated by TOTAL.

 

On the Sadang (30%), Sageri (50%), Arafura Sea (24.5%) and Amborip VI (24.5%) blocks, the Group has applied to the authorities to withdraw from these blocks. In addition, and following the withdrawal of the other partners, the Group’s stake in the South Sageri Block increased from 45% to 100% (operator), while its share in the South Mandar Block increased from 33% to 49.3%.

 

In December 2014, TOTAL sold a 20% stake in the Bengkulu I–Mentawai Block (80%, operator). This exploration block is located in the Bengkulu offshore basin southwest of Sumatra. An exploration well was drilled on the block in 2014.

 

In early 2015, the Group sold its stakes in the two coal bed methane (CBM) blocks located in the province of East Kalimantan, Kutai II (18.4%) and Kutai Timur (50%).

 

The Group also holds a stake in the Telen block (100%, operator) located in East Kalimantan province.

 

The Group has decided to withdraw from the South East Mahakam exploration block (50%, operator) located in East Kalimantan province and the South West Bird’s Head exploration block (90%, operator) located in West Papua.

In Malaysia, where TOTAL has been active since 2008, the Group holds stakes in three exploration licenses (SB-N, DW2E, SK 317 B).

In January 2014, the Group acquired a stake in the DW2E license (85%, operator) located in deep offshore. A 3D seismic campaign of 2,050 km2 was completed late 2014.

On the SK 317 B exploration block (85%, operator) located in Sarawak’s deep offshore, the first exploration well, Pelangi-1, started in December 2013, revealing gaseous hydrocarbons. A second exploration well, Pelangi-2, started in November 2014.

At the end of the exploration period, TOTAL withdrew from the PM324 Block (50%, operator), located in the Malay basin.

In Myanmar, the Group’s production in 2014 was 17 kboe/d compared with 16 kboe/d in 2013 and 2012.

The Yadana field (31.2%, operator), located on the offshore Blocks M5 and M6, primarily produces gas for delivery to PTT (Thai state-owned company) for use in Thai power plants. The Yadana field also supplies the domestic market via two pipelines built and operated by MOGE, a Myanmar state-owned company. The LCP-Badamyar project, which includes the installation of the Badamyar compression and development platform, connected to the Yadana facilities, was launched in September 2014.

In 2014, the Group was awarded the deep offshore Block YWB (100%, operator) during the offshore round launched by the Burmese authorities. The PSC was signed in February 2015.

 

 

22   TOTAL S.A. Form 20-F 2014


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Item 4 - B.2. Upstream Segment

On offshore Block M-11, located in the Martaban basin, the Group requested a new two-year exploration phase in October 2014 and, following the withdrawal of a partner, increased its stake from the 40% acquired in 2012 to approximately 47.06%. The first exploration well, Manizawta-1, was drilled in 2013.

In Papua New Guinea, where TOTAL has been active since 2012, the Group acquired a stake in Block PRL-15 (40.1%) in March 2014. The Papua New Guinea government retains the right to acquire a 22.5% stake in the block when the final investment decision is made. Following the government’s entry, TOTAL’s stake would be reduced to 31.1%.

Block PRL15 contains the two major discoveries of Elk and Antelope. A program to delineate these discoveries is currently underway with the drilling of two wells, the first of which started in October 2014, and the second of which started in December 2014. TOTAL has also launched pre-development studies of the Elk and Antelope fields, including the construction of an onshore gas liquefaction plant.

In 2012, TOTAL acquired a 40% stake in the PPL244 offshore license, and secured options to acquire 40% in the PPL234 offshore license, 50% in the PRL10 offshore license and 35% in the PPL338 and PPL339 onshore licenses.

 

 

On the offshore PPL244 license, two exploration wells were drilled in 2013.

 

The PPL234 option has not been exercised and the license expired in July 2014.

 

On the onshore PPL338 and PPL339 licenses, a 2D seismic survey was conducted in 2013. A gradiometer survey was performed on the onshore PPL339 license. The option related to the onshore PPL338 license that expired in March 2014 was not exercised due to the minimal geological interest on the license.

In the Philippines, TOTAL has held since 2012 a 75% stake in the SC56 license located in the deep offshore of the southern Sulu Sea. Following interpretation of the data from a seismic campaign in 2013, TOTAL and its partner have decided to drill an exploration well on the block. In October 2014, TOTAL became the operator of the block.

In Thailand, the Group’s production in 2014 was 60 kboe/d compared with 63 kboe/d in 2013 and 55 kboe/d in 2012. This production comes from the Bongkot (33.33%) offshore gas and condensate field. PTT purchases all of the natural gas and condensate production from this field.

 

 

In the northern portion of the Bongkot field, new investments are in progress to maintain plateau and meet gas demand:

   

phase 3L (two wellhead platforms) was approved in 2012 and commenced production in 2014;

   

phase 3M (four wellhead platforms) was approved in 2013; and

   

phase 3N (three wellhead platforms) was approved in 2014.

 

The southern portion of the field (Greater Bongkot South) is also being developed in several phases. This development is designed to include a processing platform, a living-quarters platform and thirteen production platforms:

   

phase 4A (six wellhead platforms) commenced production in 2012;

   

phase 4B (four wellhead platforms) commenced production in 2014; and

   

phase 4C (three wellhead platforms) is under development.

Exploration on these licenses is ongoing with wells drilled annually (two in 2014).

In Vietnam, the Group no longer holds any exploration interests following the sale in 2013 of its stake in offshore Block 15-1/05 (35%).

 

2.1.7.5. Commonwealth of Independent States (CIS)

In 2014, TOTAL’s production in the CIS was 249 kboe/d, representing 12% of the Group’s total production, compared with 227 kboe/d in 2013 and 195 kboe/d in 2012.

In Azerbaijan, where TOTAL has been present since 1996, production, coming entirely from the Shah Deniz field, was 14 kboe/d in 2014 compared with 20 kboe/d in 2013 and 16 kboe/d in 2012.

 

 

In August 2014, TOTAL sold its stake in the Shah Deniz field (10%) as well as its 10% stake in the pipeline held by South Caucasus Pipeline Company (SCPC).

 

In September 2014, the Group sold its 10% stake in the Trans Adriatic Pipeline (TAP).

 

TOTAL holds a 5% interest in the Baku-Tbilisi-Ceyhan (BTC) pipeline.

TOTAL is the operator for the exploration phase of the Absheron Block (40%) in the Caspian Sea, on which a discovery and commercial declaration was filed in 2012. The development plan for the field is currently being prepared.

In Kazakhstan, TOTAL has been active since 1992 in the North Caspian license (16.81%), which covers the Kashagan field.

First phase production from Kashagan (300 kb/d) started in September 2013 and was halted in October 2013 due to leaks detected on the gas export pipeline. Following investigations carried out by the consortium, a refurbishment plan for the pipelines was approved. The two oil and gas export pipelines will be replaced over 99 km.

In February 2015, TOTAL sold 23.9% of its 75% interest in the Northern and Southern Nurmunai onshore exploration blocks, located in the southwest of the country. The drilling of a well started at the end of February 2015 on Northern Nurmunai Block.

In Russia, where TOTAL has had operations since 1991 and where, as of December 31, 2014, the Group held 19% of its proved reserves, the Group’s production in 2014 was 235 kboe/d compared with 207 kboe/d in 2013 and 179 kboe/d in 2012. This production comes from the Kharyaga field and from TOTAL’s stake in the Russian company OAO Novatek (18.24%)(1), which is listed in Moscow and London (hereafter, “Novatek”). In 2014, international economic sanctions related to the situation in Ukraine were imposed by the United States, the EU and other countries. TOTAL complies with sanctions applicable to its activities. For additional information, refer to “Item 3 — C. Risk Factors”, above.

 

 

On the Kharyaga field (40%, operator), the development of phases 3 and 4 is ongoing.

 

In addition to its shareholding in Novatek, TOTAL currently participates via a direct stake in two projects:

   

Termokarstovoye (onshore gas and condensate field located in the Yamalo-Nenets district): The development and production license for the Termokarstovoye field is owned by ZAO Terneftegas, a joint venture between Novatek (51%) and TOTAL (49%). Development of the field started in late 2011 (estimated capacity of 65 kboe/d).

 

 

2014 Form 20-F TOTAL S.A.   23

 

(1) 

The Group held an 18.24% stake in OAO Novatek as of December 31, 2014.


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Item 4 - B.2. Upstream Segment

   

Yamal LNG: Launched in December 2013, the aim of this project is the development of the onshore South Tambey field (gas and condensate) located in the Yamal Peninsula via the construction of a three-train LNG liquefaction plant with a capacity of 16.5 Mt/y. In order to comply with international economic sanctions, the financing plan for the Yamal LNG project is being reviewed, and the project’s partners are engaged in efforts to develop a financing plan in line with the applicable regulations. In parallel, the development of the project is progressing in a satisfactory manner. The OAO Yamal LNG company is jointly owned by Novatek (60%), TOTAL E&P Yamal (20%) and, since January 2014, CNODC (20%), a subsidiary of CNPC.

In May 2014, TOTAL signed a strategic cooperation agreement with OAO LUKOIL in order to develop shale oil resources in the Bazhenov basin, located in the province of Kanthy Mansiysk. In addition to the licenses covered by this agreement, TOTAL acquired six new licenses in the basin in 2014. The international economic sanctions imposed in the summer of 2014 have led the partners to put this project on hold.

In January 2014, Novatek increased its stake in the Severenergia company by acquiring ENI’s shares through Arcticgaz (50/50 joint venture between Novatek and Gazpromneft). In December 2013, Novatek exchanged its interest held in Sibneftegas for all of Rosneft’s interests in Severenergia in which it now has a 54.9% stake. Novatek has held a 50% stake in the company ZAO Nortgaz since June 2013.

In Tajikistan, TOTAL launched its activities in the country by acquiring a 33.3% stake in the Bokhtar Block in the first half of 2013. Environmental and societal studies were carried out in 2014. A 2D seismic campaign covering 800 km started in 2014.

 

2.1.7.6. Europe

In 2014, TOTAL’s production in Europe was 364 kboe/d, representing 17% of the Group’s total production, compared with 392 kboe/d in 2013 and 427 kboe/d in 2012.

In Bulgaria, the Khan Asparuh license, which covers 14,220 km2 in the Black Sea, was awarded to TOTAL in 2012. In March 2013, TOTAL sold 60% of its stake, retaining a 40% interest. A 2D and 3D seismic survey was performed from June 2013 to January 2014 and the data is currently being processed and interpreted. TOTAL became the operator of the block in April 2014.

In Cyprus, TOTAL has been present since 2013 in the deep offshore exploration Block 10 (100%, operator) and Block 11 (100%, operator) located southwest of the country. Following a 3D seismic survey carried out on Block 11 in 2013, a 2D seismic survey on Block 10 was conducted in February 2014.

In Denmark, TOTAL has since 2010 held an 80% stake and operated the 1/10 (Nordjylland) and 2/10 (Nordsjaelland) licenses. These onshore licenses, whose shale gas potential continues to be assessed, cover areas of 3,000 km2 and 2,300 km2, respectively.

Following geoscience surveys on license 1/10 in 2011, the decision was made to drill a well.

On license 2/10, a gravimetric survey was completed in 2013.

In France, the Group’s production in 2014 was 2 kboe/d compared with 9 kboe/d in 2013 and 13 kboe/d in 2012.

In October 2013, TOTAL ended commercial gas operations on Lacq, which had begun in 1957. The transfer of the Lacq concession was approved by the French authorities in October 2014.

On the Lacq field, the CO2 capture, injection and storage pilot commissioned in 2010 ended in 2013.

The Montélimar exclusive exploration license awarded to TOTAL in 2010 to assess, in particular, the shale gas potential of the area, was abrogated by the government in October 2011. This revocation stemmed from the law of July 13, 2011, prohibiting the exploration and extraction of hydrocarbons by drilling followed by hydraulic fracturing. An appeal filed in December 2011 with the administrative court requesting that the judge cancel the revocation of the license is pending.

In Italy, TOTAL holds a stake in two exploration licenses and in the Tempa Rossa field (50%, operator), discovered in 1989 and located on the Gorgoglione concession (Basilicate region). The final investment decision for Tempa Rossa was made in July 2012 and development is ongoing. The Gorgoglione well was tested in 2012 and confirmed the results obtained from the other wells. A sidetrack was drilled at the TR-2 well and another started in June 2014 on the TR-1 well.

In 2013, TOTAL sold 25% of its 75% stake in Tempa Rossa, thereby reducing its stake to 50%.

In Norway, where the Group has had operations since 1965, TOTAL has equity stakes in 96 production licenses on the Norwegian maritime continental shelf, 29 of which it operates. In 2014, the Group’s production was 242 kboe/d, compared to 243 kboe/d in 2013 and 275 kboe/d in 2012. The decrease in production between 2012 and 2014 was mainly due to the natural decline of mature fields.

 

 

In the Norwegian North Sea, the most substantial contribution to the Group’s production comes from the non-operated Greater Ekofisk Area (Ekofisk, Eldfisk, Embla, etc.).

 

 

In the southern Norwegian North Sea:

In the Greater Ekofisk Area, the Group owns a 39.9% stake in the Ekofisk and Eldfisk fields. Production started in October 2013 at Ekofisk South, and in January 2015 at Eldfisk II (capacity of 70 kboe/d each).

 

 

In the central part of the Norwegian North Sea:

The development of the Gina Krog field (30%) located north of Sleipner was approved in 2013.

 

 

In the northern part of the Norwegian North Sea:

The Islay field (100%, operator) started production in 2012. This field extends on each side of the Norwegian/UK border and the Group’s interest in the Norwegian part is 5.51%.

The Stjerne field, located on license PL104 (14.7%), and the Visund South field, located on license PL120 (7.7%), were put into production in 2013 and 2012, respectively.

On license PL120 (7.7%), the fast-track development of Visund North allowed production to start in 2013.

On the Greater Hild Area (51%, operator), the Martin Linge development (capacity of 80 kboe/d) was approved by the authorities in 2012.

In 2013, the authorities approved the Oseberg Delta phase 2 project (14.7%), located on production licenses PL104 and PL79. The Oseberg East TSV project (14.7%) was approved in 2014.

 

 

In the Norwegian Sea, the Haltenbanken area includes the Tyrihans (23.2%), Mikkel (7.7%) and Kristin (6%) fields, as well as the Åsgard field (7.7%) and its satellites.

 

 

24   TOTAL S.A. Form 20-F 2014


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Item 4 - B.2. Upstream Segment

The Norwegian authorities approved the Åsgard sub-sea compression project in 2012. The main contracts have all been signed and various components were installed during the summer of 2014.

The Polarled project (5.11%), approved in 2012, involves the installation of a 481 km long pipeline from the Aasta Hansen field to the Nyhamna terminal, as well as expansion of the terminal.

 

 

In the Barents Sea, a project intended to improve the performance of the Snøhvit gas liquefaction plant (18.4%, 4.2 Mt/y capacity) was launched in 2012. The plant is supplied with gas from the Snøhvit, Albatross and Askeladd fields.

Several exploration wells were drilled on a number of licenses during the 2012-2014 period with discoveries on Helene (PL120, 11%) and Trell (PL102G, 40%, operator) in 2014, on Smørbukk North (PL479, 7.68%) and Rhea (PL120, 7.68%) in 2013, as well as on Garantiana (PL554, 40%, operator) and King Lear (PL146 and 333, 22.2%) in 2012. In 2014, the well drilled on Garantiana enabled an increase in estimated oil volumes.

In addition, the Group continues to optimize its portfolio in Norway by obtaining new licenses and divesting a number of non-strategic assets. To this end, in October 2014, TOTAL concluded an agreement to sell an 8% stake in the Gina Krog field, thereby reducing its stake to 30%, and all of its interests in the Vilje (24.24%), Vale (24.24%) and Morvin (6%) fields. The transaction was approved by the Norwegian authorities in December 2014.

In the Netherlands, TOTAL has conducted natural gas exploration and production operations since 1964 and currently holds interests in twenty-four offshore production licenses, including twenty that it operates, and two offshore exploration licenses, E17c (16.92%) and K1c (30%). In 2014, the Group’s production was 31 kboe/d compared with 35 kboe/d in 2013 and 33 kboe/d in 2012.

 

 

In September 2014, the Dutch authorities awarded the F12 exploration block to TOTAL.

 

Following the acquisition of additional stakes in 2013, TOTAL now holds a 50% stake in Block K5b and a 60% stake in Blocks K1b/K2a and K2c. TOTAL is the operator of these blocks.

 

A 3D seismic survey of several offshore licenses covering an area of 3,500 km2 was conducted in 2012.

 

In August 2013, the K4-Z development project (50%, operator) started production.

In Poland, at the beginning of 2012, TOTAL signed an agreement to acquire a 49% stake in the Chelm and Werbkowice exploration concessions in order to assess their shale gas potential. In February 2014, the licenses were relinquished, and since then the Group no longer holds any exploration interests in the country.

In the United Kingdom, where TOTAL has had operations since 1962, the Group’s production was 89 kboe/d in 2014 compared with 105 kboe/d in 2013 and 106 kboe/d in 2012. About 90% of production comes from operated fields located in two main zones: the Alwyn zone in the northern North Sea, and the Elgin/Franklin zone in the Central Graben.

 

 

In the Alwyn zone (100%), the start-up of satellite fields or new reservoir compartments partially compensated for the natural decline in production. The N54 and N53 wells were put into production in 2012 and 2011, respectively. In

   

addition, the N55 well, which was drilled in 2012 in the Brent South West panel, was put into production in the second quarter of 2014 and the N56 well (Alwyn Statfjord) in the third quarter of 2014.

On the Dunbar field (100%), a new development phase (Dunbar phase IV) including three well work-overs and the drilling of six new wells is underway.

The Islay field (100%, operator) was put into production in 2012. This field extends on either side of the border between the United Kingdom (94.49%) and Norway (5.51%). Production from the field is processed on the Alwyn North platform.

 

 

In Central Graben, TOTAL holds stakes in the Elgin, Franklin and West Franklin fields (46.2%, operator). Production at the Elgin, Franklin and West Franklin fields was stopped following a gas leak on the Elgin field in March 2012. In May 2012, the G4 well was definitively secured. Production in the Elgin/Franklin area resumed in March 2013 following the approval of the safety case by the UK Health and Safety Executive (HSE). A redevelopment project involving the drilling of five new infill wells on Elgin and Franklin started in July 2013.

In 2014, TOTAL acquired an additional interest (9.5%) in the Glenelg field, thereby increasing its interest from 49.5% to 58.7%.

In addition, the West Franklin Phase II development project continued with the start-up of production of the first well in January 2015.

 

 

In addition to Alwyn and the Central Graben, a third hub, West of Shetland, is under development. This hub includes the Laggan and Tormore fields (80%, operator) and the P967 license (50%, operator), which includes the Tobermory gas discovery. Production on the Laggan and Tormore fields is expected to start in 2015 with an expected capacity of 90 kboe/d.

Close to Laggan and Tormore, the development of the Edradour East (80%, operator) gas and condensate discovery was sanctioned in 2012. A second well (Spinnaker), near the Edradour East discovery, was drilled in early 2014.

In July 2014, TOTAL acquired an 80% stake and the operatorship in the Glenlivet field located north of Edradour. The proximity of the two fields resulted in reduced costs, which enabled the launch of a joint development.

In addition, TOTAL purchased an additional 5% stake in the Edradour field in 2014 and now holds 80% of the four fields currently under development: Laggan, Tormore, Edradour and Glenlivet.

TOTAL also holds a stake in three non-operated fields: Bruce (43.25%), Keith (25%), and Markham (7.35%). The Group’s stakes in other non-operated fields (Seymour, Alba, Armada, Maria, Moira, Mungo/Monan and Everest) were divested in 2012.

TOTAL was awarded six new licenses in the 28th Round in November 2014. Four of these licenses are in the West of Shetland area, one in the northern North Sea and one non-operated in the Central Graben.

In early 2014, TOTAL acquired a 40% stake in two onshore shale gas exploration and production licenses (PEDL 139 and 140) located in the Gainsborough Trough basin of the East Midlands, and signed an agreement enabling the Group to acquire a 50% stake in the PEDL 209 license located in the same area. A 70 km2 3D survey campaign was carried out in March and April 2014.

 

 

2014 Form 20-F TOTAL S.A.   25


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Item 4 - B.2. Upstream Segment

2.1.7.7. Middle East

In 2014, TOTAL’s production in the Middle East was 391 kboe/d, representing 18% of the Group’s total production, compared with 536 kboe/d in 2013 and 493 kboe/d in 2012.

In the United Arab Emirates, where TOTAL has had operations since 1939, the Group’s production was 127 kboe/d in 2014 compared with 260 kboe/d in 2013 and 246 kboe/d in 2012. The decrease in production in 2014 was due to the expiry of the Abu Dhabi Company for Onshore oil Operations (ADCO) license in January 2014, in which TOTAL held a 9.5% interest. In January 2015, TOTAL signed an agreement granting it a 10% participation as from January 1, 2015 in the new ADCO concession for 40 years. This concession covers the fifteen main onshore fields of Abu Dhabi and represents more than half of the Emirate’s production.

TOTAL holds a 75% stake (operator) in the Abu Al Bukhoosh field and a 13.3% stake in Abu Dhabi Marine Operating Company (ADMA-OPCO), which operates two fields offshore Abu Dhabi. TOTAL also holds a 15% stake in Abu Dhabi Gas Industries (GASCO), which produces NGL and condensates from the associated gas produced by ADCO as well as from the gas and condensates produced by ADMA-OPCO. In addition, TOTAL holds stakes of 5% in Abu Dhabi Gas Liquefaction Company (ADGAS), which processes the associated gas produced by ADMA-OPCO in order to produce LNG, NGL and condensates, and 5% in National Gas Shipping Company (NGSCO), which owns eight LNG tankers and exports the LNG produced by ADGAS.

The Group holds a 24.5% stake in Dolphin Energy Ltd. in partnership with Mubadala, a company owned by the government of Abu Dhabi, in order to market gas produced in Qatar primarily to the United Arab Emirates.

The Group also owns 33.33% of Ruwais Fertilizer Industries (FERTIL), which produces urea. The FERTIL 2 project commenced operations in July 2013, enabling FERTIL to more than double its production capacity to 2 Mt/y.

In Iraq, the Group’s production in 2014 was 12 kboe/d compared with 7 kboe/d in 2013 and 6 kboe/d in 2012.

On the Halfaya field in Missan province, following the completion of a negotiation in October 2014, TOTAL’s stake increased from 18.75% to 22.5% in the consortium that was awarded the development and production contract. Production of phase 1 of the project started in June 2012 and phase 2 started in August 2014, enabling production to reach 200 kb/d in the second half of 2014.

In early 2014, TOTAL increased its stake from 35% to 80% and became operator of the Safen Block (424 km2) located northwest of Erbil in the Kurdistan region. A 2D seismic survey of 275 km was conducted in 2014.

In early 2013, TOTAL acquired an 80% stake and became operator of the Baranan exploration Block (729 km2), southeast of Sulaymaniyah, in the Kurdistan region. A 2D seismic survey of 213 km was completed in January 2014.

Since 2012, TOTAL has held a 35% stake in the Harir exploration Block (705 km2) located northeast of Erbil, as well as a 20% stake in the Taza Block (505 km2), located southwest of Sulaymaniyah. Following three exploration wells in 2013 that led to two

discoveries on the Taza Block and on the Harir Block (Mirawa), an exploration well was drilled in 2014 resulting in the Jisik discovery.

In Iran, the Group has had no production since 2010. For additional information, refer to “— C. Other Matters — 8. Cuba, Iran and Syria”, below.

In Oman, the Group’s production in 2014 was 36 kboe/d, stable compared with 2013 and 2012. TOTAL primarily produces oil on Block 6 (4%)(1) as well as on Block 53 (2%)(2). The Group also produces LNG through its stake in the Oman LNG (5.54%)/Qalhat LNG (2.04%)(3) liquefaction plant, which has a capacity of 10.5 Mt/y. In December 2013, TOTAL obtained the license for ultra-deep offshore Block 41, in which a seabed core drilling campaign was carried out.

In Qatar, where TOTAL has had operations since 1936, the Group’s production was 132 kboe/d in 2014 compared with 137 kboe/d in 2013 and 139 kboe/d in 2012.

The Group operates the Al Khalij field and participates in the production, processing and export of gas from the North Field through its stakes in the Qatargas 1 and Qatargas 2 liquefied natural gas (LNG) plants and in Dolphin Energy.

 

 

Al Khalij (40%, operator): in 2012, TOTAL and state-owned Qatar Petroleum signed a new agreement extending their partnership on the Al Khalij field for an additional 25-year period as of February 1, 2014. According to the terms of this contract, TOTAL will continue to be the operator (40%) alongside Qatar Petroleum (60%).

 

Qatargas 2 (16.7%): the production capacity of train 5 of Qatargas 2 is 8 Mt/y. TOTAL offtakes part of the LNG produced under the 2006 contracts which provide for the purchase of 5.2 Mt/y of LNG by the Group. In addition, the Group holds a stake in the Qatargas 1 liquefaction plant (10%), as well as a stake in the corresponding upstream block NFB (20%).

 

Dolphin Energy (24.5%): the production contract for the Dolphin gas project, signed in 2001 with Qatar Petroleum, provides for the sale of 2 Bcf/d of gas from the North Field for a 25-year period. The gas is processed in the Dolphin plant in Ras Laffan and exported to the United Arab Emirates through a 360 km gas pipeline.

 

The Group became a partner in the offshore BC exploration license (25%) in 2011. Drilling of the first exploration well started in May 2014 and was completed in December 2014.

In Syria, TOTAL has a 100% stake in the Deir Ez Zor license, which is operated by the joint venture company DEZPC in which TOTAL and the state-owned company SPC each have a 50% share. TOTAL also holds the Tabiyeh contract, which came into effect in 2009. The Group has had no production in the country since December 2011, when TOTAL suspended its hydrocarbon production activities in Syria in compliance with the European Union’s regulations regarding this country. For additional information, refer to “Item 4 — C. Other Matters — 8. Cuba, Iran and Syria”, below.

In Yemen, where TOTAL has had operations since 1987, the Group’s production was 84 kboe/d in 2014 compared with 95 kboe/d in 2013 and 65 kboe/d in 2012.

The security situation in Yemen remains unstable, however this had only a marginal effect on the production from the Group’s assets in 2014. Security measures are regularly reviewed in view of the evolving risks.

 

 

26   TOTAL S.A. Form 20-F 2014

 

(1) 

TOTAL holds an indirect 4% stake in Petroleum Development Oman LLC, operator of Block 6 via its 10% stake in Private Oil Holdings Oman Ltd.

(2) 

TOTAL holds a 2% stake in Block 53.

(3) 

TOTAL has an indirect stake via Oman LNG’s stake in Qalhat LNG.


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Item 4 - B.2. Upstream Segment

TOTAL owns a 39.62% stake in the Yemen LNG liquefaction plant (capacity of 6.7 Mt/y), which is located in Balhaf on the country’s southern coast. This plant is supplied with the gas produced on Block 18, located near Marib in the center of the country, and connected via a 320 km gas pipeline. Rockets were launched towards the Balhaf plant in December 2013, January 2014 and December 2014. However, production was not impacted and security measures have been strengthened.

TOTAL also has stakes in two oil blocks: Block 10 East Shabwa license (28.57%, operator) in the Masila basin and Block 5 Jannah license (15%) in the Marib basin.

TOTAL owns stakes in five onshore exploration licenses: Block 69 (40%, the exploration period has expired and the block is in the process of being relinquished), Block 71 (40%), Block 70 (50.1%, operator), Block 72 (36%, operator), and Block 3 (40%, operator).

 

 

2014 Form 20-F TOTAL S.A.   27


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Item 4 - B.2. Upstream Segment

2.1.8. Oil and gas acreage

 

As of December 31,

(in thousands of acres)

  2014  
     Undeveloped
acreage
(a)
    Developed
acreage
 

Europe

  Gross     10,601        692   
    Net     5,197        143   

Africa

  Gross     122,385        1,306   
    Net     79,562        350   

Americas

  Gross     25,081        962   
    Net     11,375        299   

Middle East

  Gross     34,375        1,215   
    Net     9,908        129   

Asia (excl. Russia)

  Gross     50,076        705   
    Net     26,930        253   

Russia

  Gross     3,419        1,370   
    Net     1,334        215   

Total

  Gross     245,937        6,250   
    Net(b)     134,306        1,389   

 

(a) 

Undeveloped acreage includes leases and concessions.

(b) 

Net acreage equals the sum of the Group’s equity stakes in gross acreage.

 

2.1.9. Number of productive wells

 

As of December 31,

   2014  
      Gross
productive
wells
     Net
productive
wells
(a)
 

Europe

   Oil      370         101   
     Gas      279         82   

Africa

   Oil      2,297         619   
     Gas      158         49   

Americas

   Oil      961         295   
     Gas      3,817         782   

Middle East

   Oil      5,540         355   
     Gas      107         20   

Asia (excl. Russia)

   Oil      140         57   
     Gas      2,063         732   

Russia

   Oil      137         31   
     Gas      410         67   

Total

   Oil      9,445         1,458   
     Gas      6,834         1,732   

 

(a) 

Net wells equal the sum of the Group’s equity stakes in gross wells.

 

28   TOTAL S.A. Form 20-F 2014


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Item 4 - B.2. Upstream Segment

2.1.10. Number of net productive and dry wells drilled

 

As of December 31,

  2014     2013     2012  
     Net
productive
wells
drilled
(a)(b)
    Net dry
wells
drilled
(a)(c)
    Net total
wells
drilled
(a)(c)
    Net
productive
wells
drilled
(a)(b)
    Net dry
wells
drilled
(a)(c)
    Net total
wells
drilled
(a)(c)
    Net
productive
wells
drilled
(a)(b)
    Net dry
wells
drilled
(a)(c)
    Net total
wells
drilled
(a)(c)
 

Exploratory

 

Europe

    1.4        0.2        1.6        1.5        0.2        1.7        0.9        3.3        4.2   
 

Africa

    2.0        3.3        5.3        1.5        5.1        6.6        4.9        2.8        7.7   
 

Americas

    2.1        0.3        2.4        2.9        1.4        4.3        3.9        0.6        4.5   
 

Middle East

    0.3        0.3        0.6        0.6        0.7        1.3                        
 

Asia (excl. Russia)

    1.2        1.1        2.3        1.6        4.3        5.9        2.4        1.4        3.8   
 

Russia

           0.3        0.3