falsedesktopTOT2010-12-31000095012311029588{"tbl_sim": "https://q10k.com/tbl-sim", "search": "https://q10k.com/search"}{"q10k_tbl_0": "(Mark One)\t\no\tREGISTRATION STATEMENT PURSUANT TO SECTION 12(b) OR 12(g) OF THE SECURITIES EXCHANGE ACT OF 1934\nOR\t\nx\tANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934\nFor the fiscal year ended December 31 2010\t\nOR\t\no\tTRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934\n\tFor the transition period from to\nOR\t\no\tSHELL COMPANY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934\n\tDate of event requiring this shell company report\n", "q10k_tbl_1": "\t\tPage\nCERTAIN TERMS\t\tiii\nABBREVIATIONS\t\tiv\nCONVERSION TABLE\t\tv\nItem 1.\tIdentity of Directors Senior Management and Advisers\t1\nItem 2.\tOffer Statistics and Expected Timetable\t1\nItem 3.\tKey Information\t1\n\tSelected Financial Data\t1\n\tExchange Rate Information\t3\n\tRisk Factors\t4\nItem 4.\tInformation on the Company\t9\n\tHistory and Development\t9\n\tBusiness Overview\t10\n\tOther Matters\t51\nItem 4A.\tUnresolved Staff Comments\t62\nItem 5.\tOperating and Financial Review and Prospects\t62\nItem 6.\tDirectors Senior Management and Employees\t77\n\tDirectors and Senior Management\t77\n\tCompensation\t85\n\tCorporate Governance\t108\n\tEmployees and Share Ownership\t114\nItem 7.\tMajor Shareholders and Related Party Transactions\t118\nItem 8.\tFinancial Information\t120\nItem 9.\tThe Offer and Listing\t125\nItem 10.\tAdditional Information\t127\nItem 11.\tQuantitative and Qualitative Disclosures About Market Risk\t138\nItem 12.\tDescription of Securities Other than Equity Securities\t138\nItem 13.\tDefaults Dividend Arrearages and Delinquencies\t139\nItem 14.\tMaterial Modifications to the Rights of Security Holders and Use of Proceeds\t139\nItem 15.\tControls and Procedures\t140\nItem 16A.\tAudit Committee Financial Expert\t140\nItem 16B.\tCode of Ethics\t140\nItem 16C.\tPrincipal Accountant Fees and Services\t141\nItem 16D.\tExemptions from the Listing Standards for Audit Committees\t141\nItem 16E.\tPurchases of Equity Securities by the Issuer and Affiliated Purchasers\t142\nItem 16F.\tChange in Registrant's Certifying Accountant\t142\nItem 16G.\tCorporate Governance\t143\nItem 17.\tFinancial Statements\t145\nItem 18.\tFinancial Statements\t145\nItem 19.\tExhibits\t146\nEX-1\t\t\t\t\nEX-12.1\t\t\t\t\nEX-12.2\t\t\t\t\nEX-13.1\t\t\t\t\nEX-13.2\t\t\t\t\nEX-15\t\t\t\t\n", "q10k_tbl_2": "\"acreage''\tThe total area expressed in acres over which TOTAL has interests in exploration or production.\n\"ADRs''\tAmerican Depositary Receipts evidencing ADSs.\n\"ADSs''\tAmerican Depositary Shares representing the shares of TOTAL S.A.\n\"barrels''\tBarrels of crude oil natural gas liquids (NGL) or bitumen.\n\"Company''\tTOTAL S.A.\n\"condensates''\tCondensates 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+.\n\"crude oil''\tCrude 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 natural gas liquids (NGL).\n\"Depositary''\tThe Bank of New York Mellon.\n\"Depositary Agreement''\tThe depositary agreement pursuant to which ADSs are issued a copy of which is attached as Exhibit 1 to the registration statement on Form F-6 (Reg. No. 333-172005) filed with the SEC on February 1 2011.\n\"Group''\tTOTAL S.A. and its subsidiaries and affiliates. The terms TOTAL and Group are used interchangeably.\n\"hydrocracker''\tA refinery unit which uses a catalyst and extraordinarily high pressure in the presence of surplus hydrogen to shorten molecules.\n\"liquids''\tLiquids consist of crude oil bitumen and natural gas liquids (NGL).\n\"LNG''\tLiquefied natural gas.\n\"LPG''\tLiquefied 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\n\"NGL''\tNatural gas liquids consist of condensates and liquefied petroleum gas (LPG).\n\"oil and gas\"\tGeneric term which includes all hydrocarbons (e.g. crude oil natural gas liquids (NGL) bitumen and natural gas).\n\"proved reserves''\tProved 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).\n", "q10k_tbl_3": "\"proved developed reserves''\tProved 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 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).\n\"proved undeveloped reserves''\tProved 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 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).\n\"steam cracker''\tA petrochemical plant that turns naphtha and light hydrocarbons into ethylene propylene and other chemical raw materials.\n\"TOTAL''\tTOTAL 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.\n\"trains''\tFacilities for converting liquefying storing and off-loading natural gas.\n\"ERMI''\tERMI is an 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.\n\"turnarounds''\tTemporary shutdowns of facilities for maintenance overhaul and upgrading.\n", "q10k_tbl_4": "1 acre\t= 0.405 hectares\t\n1 b\t= 42 U.S. gallons\t\n1 boe\t= 1 b of crude oil\t= 5478 cf of gas in 2010(a)\n\t\t= 5490 cf of gas in 2009\n\t\t= 5505 cf of gas in 2008\n1 b/d of crude oil\t= approximately 50 t/y of crude oil\t\n1 Bm3/y\t= approximately 0.1 Bcf/d\t\n1 m3\t= 35.3147 cf\t\n1 kilometer\t= approximately 0.62 miles\t\n1 ton\t= 1 t\t= 1000 kilograms (approximately 2205 pounds)\n1 ton of oil\t= 1 t of oil\t= approximately 7.5 b of oil (assuming a specific gravity of 37° API)\n1 t of LNG\t= approximately 48 kcf of gas\t\n1 Mt/y LNG\t= approximately 131 Mcf/d\t\n", "q10k_tbl_5": "(M€ except per share data)\t2010\t\t2009\t2008\t2007\t2006\nINCOME STATEMENT DATA\t\t\t\t\t\t\nRevenues from sales\t140476\t\t112153\t160331\t136824\t132689\nNet income Group share\t10571\t\t8447\t10590\t13181\t11768\nEarnings per share\t4.73\t\t3.79\t4.74\t5.84\t5.13\nFully diluted earnings per share\t4.71\t\t3.78\t4.71\t5.80\t5.09\nCASH FLOW STATEMENT DATA(a)(b)\t\t\t\t\t\t\nCash flow from operating activities\t18493\t\t12360\t18669\t17686\t16061\nTotal expenditures\t16273\t\t13349\t13640\t11722\t11852\nBALANCE SHEET DATA(b)\t\t\t\t\t\t\nTotal assets\t143718\t\t127753\t118310\t113541\t105223\nNon-current financial debt\t20783\t\t19437\t16191\t14876\t14174\nMinority interests\t857\t\t987\t958\t842\t827\nShareholders' equity - Group share\t60414\t\t52552\t48992\t44858\t40321\nCommon shares\t5874\t\t5871\t5930\t5989\t6064\nDIVIDENDS\t\t\t\t\t\t\nDividend per share (euros)\t€2.28\t(c)\t€2.28\t€2.28\t€2.07\t€1.87\nDividend per share (dollars)\t3.02\t(c)(d)\t3.08\t3.01\t3.14\t2.46\nCOMMON SHARES(e)\t\t\t\t\t\t\nAverage number outstanding of common shares €2.50 par value (shares undiluted)\t2234829043\t\t2230599211\t2234856551\t2255294231\t2293063190\nAverage number outstanding of common shares €2.50 par value (shares diluted)\t2244494576\t\t2237292199\t2246658542\t2274384984\t2312304652\n", "q10k_tbl_6": "(a)\tSee Consolidated Statement of Cash Flows included in the Consolidated Financial Statements.\n(b)\tComparative cash flow information for 2006 includes Arkema which was spun off on May 12 2006.\n(c)\tSubject to approval by the shareholders' meeting on May 13 2011.\n(d)\tEstimated dividend in dollars includes the interim dividend of $1.542 paid in November 2010 and the proposed final dividend of €1.14 converted at a rate of $1.30/€.\n(e)\tThe number of common shares shown has been used to calculate per share amounts.\n", "q10k_tbl_7": "Year\tAverage Rate\n2006\t1.2556\n2007\t1.3705\n2008\t1.4708\n2009\t1.3948\n2010\t1.3257\n", "q10k_tbl_8": "Period\tHigh\tLow\nOctober 2010\t1.41\t1.37\nNovember 2010\t1.42\t1.30\nDecember 2010\t1.34\t1.31\nJanuary 2011\t1.37\t1.29\nFebruary 2011\t1.38\t1.34\nMarch 2011(a)\t1.42\t1.38\n", "q10k_tbl_9": "\t\tRest of\tNorth\t\t\t\n(M€)\tFrance\tEurope\tAmerica\tAfrica\tRest of world\tTotal\n2010\t\t\t\t\t\t\nNon-Group sales(a)\t36820\t72636\t12432\t12561\t24820\t159269\nProperty plant and equipment intangible assets net\t5666\t14568\t9584\t20166\t13897\t63881\nCapital expenditures\t1062\t2629\t3626\t4855\t4101\t16273\n2009\t\t\t\t\t\t\nNon-Group sales(a)\t32437\t60140\t9515\t9808\t19427\t131327\nProperty plant and equipment intangible assets net\t6973\t15218\t8112\t17312\t11489\t59104\nCapital expenditures\t1189\t2502\t1739\t4651\t3268\t13349\n2008\t\t\t\t\t\t\nNon-Group sales(a)\t43616\t82761\t14002\t12482\t27115\t179976\nProperty plant and equipment intangible assets net\t7260\t13485\t5182\t15460\t10096\t51483\nCapital expenditures\t1997\t2962\t1255\t4500\t2926\t13640\n", "q10k_tbl_10": "\t2010\t\t\t2009\t\t\t2008\t\t\n\t\tNatural\t\t\tNatural\t\t\tNatural\t\n\tLiquids\tgas\tTotal\tLiquids\tgas\tTotal\tLiquids\tgas\tTotal\n\tkb/d\tMcf/d\tkboe/d\tkb/d\tMcf/d\tkboe/d\tkb/d\tMcf/d\tkboe/d\nAfrica\t616\t712\t756\t632\t599\t749\t654\t659\t783\nAlgeria\t25\t87\t41\t47\t143\t74\t51\t145\t79\nAngola\t157\t34\t163\t186\t33\t191\t200\t33\t205\nCameroon\t9\t2\t9\t12\t2\t12\t13\t2\t14\nThe Congo Republic of\t115\t27\t120\t101\t27\t106\t85\t23\t89\nGabon\t63\t20\t67\t67\t20\t71\t73\t20\t76\nLibya\t55\t0\t55\t60\t0\t60\t74\t0\t74\nNigeria\t192\t542\t301\t159\t374\t235\t158\t436\t246\nNorth America\t30\t199\t65\t20\t22\t24\t11\t15\t14\nCanada(a)\t10\t0\t10\t8\t0\t8\t8\t0\t8\nUnited States\t20\t199\t55\t12\t22\t16\t3\t15\t6\nSouth America\t76\t569\t179\t80\t564\t182\t119\t579\t224\nArgentina\t14\t381\t83\t15\t364\t80\t14\t365\t81\nBolivia\t3\t94\t20\t3\t91\t20\t3\t105\t22\nColombia\t11\t34\t18\t13\t45\t23\t14\t45\t23\nTrinidad & Tobago\t3\t2\t3\t5\t2\t5\t6\t2\t6\nVenezuela\t45\t58\t55\t44\t62\t54\t82\t62\t92\nAsia-Pacific\t28\t1237\t248\t33\t1228\t251\t29\t1236\t246\nAustralia\t0\t6\t1\t0\t0\t0\t0\t0\t0\nBrunei\t2\t59\t14\t2\t49\t12\t2\t60\t14\nIndonesia\t19\t855\t178\t25\t898\t190\t21\t857\t177\nMyanmar\t0\t114\t14\t0\t103\t13\t0\t117\t14\nThailand\t7\t203\t41\t6\t178\t36\t6\t202\t41\nCIS\t13\t56\t23\t14\t52\t24\t12\t75\t26\nAzerbaijan\t3\t54\t13\t3\t50\t12\t4\t73\t18\nRussia\t10\t2\t10\t11\t2\t12\t8\t2\t8\nEurope\t269\t1690\t580\t295\t1734\t613\t302\t1704\t616\nFrance\t5\t85\t21\t5\t100\t24\t6\t103\t25\nThe Netherlands\t1\t234\t42\t1\t254\t45\t1\t244\t44\nNorway\t183\t683\t310\t199\t691\t327\t204\t706\t334\nUnited Kingdom\t80\t688\t207\t90\t689\t217\t91\t651\t213\nMiddle East\t308\t1185\t527\t307\t724\t438\t329\t569\t432\nUnited Arab Emirates\t207\t76\t222\t201\t72\t214\t228\t74\t243\nIran\t2\t0\t2\t8\t0\t8\t9\t0\t9\nOman\t23\t55\t34\t22\t56\t34\t23\t59\t34\nQatar\t49\t639\t164\t50\t515\t141\t44\t434\t121\nSyria\t14\t130\t39\t14\t34\t20\t15\t2\t15\nYemen\t13\t285\t66\t12\t47\t21\t10\t0\t10\nTotal production\t1340\t5648\t2378\t1381\t4923\t2281\t1456\t4837\t2341\nIncluding share of equity and non-consolidated affiliates\t300\t781\t444\t286\t395\t359\t347\t298\t403\nAlgeria\t19\t4\t20\t20\t3\t21\t19\t4\t20\nColombia\t7\t0\t7\t6\t0\t6\t5\t0\t5\nVenezuela\t45\t6\t46\t44\t6\t45\t82\t6\t83\nUnited Arab Emirates\t199\t66\t212\t191\t62\t202\t218\t64\t231\nOman\t22\t55\t32\t22\t56\t34\t23\t59\t34\nQatar\t8\t367\t75\t3\t221\t42\t0\t165\t30\nYemen\t0\t283\t52\t0\t47\t9\t0\t0\t0\n", "q10k_tbl_11": "\tYear of\t\t\n\tentry into\tOperated\tNon-operated\n\tthe country\t(Group share in %)\t(Group share in %)\nAfrica\t\t\t\nAlgeria\t1952\t\t\n\t\t\tOurhoud (19.41%)(b)\n\t\t\tRKF (48.83%)(b)\n\t\t\tTin Fouye Tabankort (35.00%)\nAngola\t1953\tBlocks 3-85 3-91 (50.00%)\t\n\t\tGirassol Jasmim\t\n\t\tRosa Dalia (Block 17) (40.00%)\t\n\t\t\tCabinda (Block 0) (10.00%)\n\t\t\tKuito BBLT Tombua-Landana (Block 14) (20.00%)\nCameroon\t1951\tBakingili (25.50%)\t\n\t\tBavo-Asoma (25.50%)\t\n\t\tBoa Bakassi (25.50%)\t\n\t\tEkundu Marine (25.50%)\t\n\t\tKita Edem (25.50%)\t\n\t\tKole Marine (25.50%)\t\n\t\t\tMokoko - Abana (10.00%)\n\t\t\tMondoni (25.00%)\nThe Congo Republic of\t1928\tKombi-Likalala (65.00%)\t\n\t\tNkossa (53.50%)\t\n\t\tNsoko (53.50%)\t\n\t\tMoho Bilondo (53.50%)\t\n\t\tSendji (55.25%)\t\n\t\tTchendo (65.00%)\t\n\t\tTchibeli-Litanzi-Loussima (65.00%)\t\n\t\tTchibouela (65.00%)\t\n\t\tYanga (55.25%)\t\n\t\t\tLoango (50.00%)\n\t\t\tZatchi (35.00%)\nGabon\t1928\tAnguille (100.00%)\t\n\t\tAnguille Nord Est (100.00%)\t\n\t\tAnguille Sud-Est (100.00%)\t\n\t\tAtora (40.00%)\t\n\t\tAvocette (57.50%)\t\n\t\tAyol Marine (100.00%)\t\n\t\tBaliste (50.00%)\t\n\t\tBarbier (100.00%)\t\n\t\tBaudroie Marine (50.00%)\t\n\t\tBaudroie Nord Marine (50.00%)\t\n\t\tCoucal (57.50%)\t\n\t\tGirelle (100.00%)\t\n\t\tGonelle (100.00%)\t\n\t\tGrand Anguille Marine (100.00%)\t\n\t\tGrondin (100.00 %)\t\n\t\tHylia Marine (75.00%)\t\n\t\tLopez Nord (100.00%)\t\n\t\tMandaros (100.00%)\t\n\t\tM'Boumba (100.00%)\t\n\t\tMérou Sardine Sud (50.00%)\t\n\t\tPageau (100.00%)\t\n\t\tPort Gentil Océan (100.00%)\t\n\t\tPort Gentil Sud Marine (100.00%)\t\n\t\tTchengue (100.00%)\t\n\t\tTorpille (100.00%)\t\n\t\tTorpille Nord Est (100.00%)\t\n\t\t\tRabi Kounga (47.50%)\n", "q10k_tbl_12": "\tYear of\t\t\n\tentry into\tOperated\tNon-operated\n\tthe country\t(Group share in %)\t(Group share in %)\nLibya\t1959\t\tC 17 (Mabruk) (15.00%)\n\t\t\tC 137 (Al Jurf) (20.25%)\n\t\t\tNC 115 (El Sharara) (3.90%)\n\t\t\tNC 186 (2.88%)\nNigeria\t1962\tOML 58 (40.00%)\t\n\t\tOML 99 Amenam-Kpono (30.40%)\t\n\t\tOML 100 (40.00%)\t\n\t\tOML 102 (40.00%)\tOML 102 - Ekanga (40.00%)\n\t\tOML 130 (24.00%)\t\n\t\t\tShell Petroleum Development Company (SPDC 10.00%)\n\t\t\tOML 118 - Bonga (12.50%)\nNorth America\t\t\t\nCanada\t1999\t\tSurmont (50.00%)\nUnited States\t1957\t\tSeveral assets in the Barnett Shale area (25.00%)\n\t\t\tTahiti (17.00%)\nSouth America\t\t\t\nArgentina\t1978\tAguada Pichana (27.27%)\t\n\t\tAries (37.50%)\t\n\t\tCañadon Alfa Complex (37.50%)\t\n\t\tCarina (37.50%)\t\n\t\tHidra (37.50%)\t\n\t\tSan Roque (24.71%)\t\n\t\t\tSierra Chata (2.51%)\nBolivia\t1995\t\tSan Alberto (15.00%)\n\t\t\tSan Antonio (15.00%)\nColombia\t1973\t\tCaracara (34.18%)(i)\n\t\t\tCusiana (11.60%)\n\t\t\tEspinal (7.32%)(i)\n\t\t\tSan Jacinto/Rio Paez (8.14%)(i)\nTrinidad & Tobago\t1996\t\tAngostura (30.00%)\nVenezuela\t1980\t\tPetroCedeño (30.323%)\n\t\t\tYucal Placer (69.50%)\nAsia-Pacific\t\t\t\nAustralia\t2005\t\tGLNG (20.00%)\nBrunei\t1986\tMaharaja Lela Jamalulalam (37.50%)\t\nIndonesia\t1968\tBekapai (50.00%)\t\n\t\tHandil (50.00%)\t\n\t\tPeciko (50.00%)\t\n\t\tSisi-Nubi (47.90%)\t\n\t\tTambora (50.00%)\t\n\t\tTunu (50.00%)\t\n\t\t\tBadak (1.05%)\n\t\t\tNilam - gas and condensates (9.29%)\n\t\t\tNilam - oil (10.58%)\nMyanmar\t1992\tYadana (31.24%)\t\nThailand\t1990\t\tBongkot (33.33%)\nCIS\t\t\t\nAzerbaijan\t1996\t\tShah Deniz (10.00%)\nRussia\t1989\tKharyaga (40.00%)\t\nEurope\t\t\t\nFrance\t1939\tLacq (100.00%)\t\n\t\tMeillon (100.00%)\t\n\t\tPecorade (100.00%)\t\n", "q10k_tbl_13": "\tYear of\t\t\n\tentry into\tOperated\tNon-operated\n\tthe country\t(Group share in %)\t(Group share in %)\n\t\tVic-Bilh (73.00%)\t\n\t\tLagrave (100.00%)\t\n\t\tLanot (100.00%)\t\n\t\t\tDommartin-Lettrée (56.99%)\n\t\tItteville (78.73%)\t\n\t\tLa Croix-Blanche (100.00%)\t\n\t\tRousse (100.00%)\t\n\t\tVert-le-Grand (90.05%)\t\n\t\tVert-le-Petit (100.00%)\t\nNorway\t1965\tSkirne (40.00%)\t\n\t\t\tÅsgard (7.68%)\n\t\t\tEkofisk (39.90%)\n\t\t\tEldfisk (39.90%)\n\t\t\tEmbla (39.90%)\n\t\t\tGimle (4.90%)\n\t\t\tGlitne (21.80%)\n\t\t\tGungne (10.00%)\n\t\t\tHeimdal (16.76%)\n\t\t\tHuldra (24.33%)\n\t\t\tKristin (6.00%)\n\t\t\tKvitebjørn (5.00%)\n\t\t\tMikkel (7.65%)\n\t\t\tMorvin (6.00%)\n\t\t\tOseberg (10.00%)\n\t\t\tOseberg East (10.00%)\n\t\t\tOseberg South (10.00%)\n\t\t\tSleipner East (10.00%)\n\t\t\tSleipner West (9.41%)\n\t\t\tSnøhvit (18.40%)\n\t\t\tSnorre (6.18%)\n\t\t\tStatfjord East (2.80%)\n\t\t\tSygna (2.52%)\n\t\t\tTor (48.20%)\n\t\t\tTordis (5.60%)\n\t\t\tTroll I (3.69%)\n\t\t\tTroll II (3.69%)\n\t\t\tTune (10.00%)\n\t\t\tTyrihans (23.18%)\n\t\t\tVale (24.24%)\n\t\t\tVigdis (5.60%)\n\t\t\tVilje (24.24%)\n\t\t\tVisund (7.70%)\n\t\t\tYttergryta (24.50%)\nThe Netherlands\t1964\tF6a gaz (55.66%)\t\n\t\tF6a huile (65.68%)\t\n\t\tF15a Jurassic (38.20%)\t\n\t\tF15a/F15d Triassic (32.47%)\t\n\t\tF15d (32.47%)\t\n\t\tJ3a (30.00%)\t\n\t\tK1a (40.10%)\t\n\t\tK1b/K2a (54.33%)\t\n\t\tK2c (54.33%)\t\n\t\tK3b (56.16%)\t\n\t\tK3d (56.16%)\t\n\t\tK4a (50.00%)\t\n\t\tK4b/K5a (36.31%)\t\n\t\tK5b (45.27%)\t\n\t\tK6/L7 (56.16%)\t\n\t\tL1a (60.00%)\t\n", "q10k_tbl_14": "\tYear of\t\t\n\tentry into\tOperated\tNon-operated\n\tthe country\t(Group share in %)\t(Group share in %)\n\t\tL1d (60.00%)\t\n\t\tL1e (55.66%)\t\n\t\tL1f (55.66%)\t\n\t\tL4a (55.66%)\t\n\t\t\tE16a (16.92%)\n\t\t\tE17a/E17b (14.10%)\n\t\t\tJ3b/J6 (25.00%)\n\t\t\tQ16a (6.49%)\nUnited Kingdom\t1962\tAlwyn North Dunbar Ellon Grant\t\n\t\tNuggets (100.00%)\t\n\t\tElgin-Franklin (EFOG 46.17%)(c)\t\n\t\tForvie Nord (100.00%)\t\n\t\tGlenelg (49.47%)\t\n\t\tJura (100.00%)\t\n\t\tOtter (81.00%)\t\n\t\tWest Franklin (EFOG 46.17%)(c)\t\n\t\t\tAlba (12.65%)\n\t\t\tArmada (12.53%)\n\t\t\tBruce (43.25%)\n\t\t\tMarkham unitized fields (7.35%)\n\t\t\tETAP (Mungo. Monan) (12.43%)\n\t\t\tEverest (0.87%)\n\t\t\tKeith (25.00%)\n\t\t\tMaria (28.96%)\n\t\t\tSeymour (25.00%)\nMiddle East\t\t\t\nU.A.E.\t1939\tAbu Dhabi -Abu Al Bu Khoosh (75.00%)\t\n\t\t\tAbu Dhabi offshore (13.33%)(d)\n\t\t\tAbu Dhabi onshore (9.50%)(e)\n\t\t\tGASCO (15.00%)\n\t\t\tADGAS (5.00%)\nOman\t1937\t\tVarious fields onshore (Block 6) (4.00%)(f)\n\t\t\tMukhaizna field (Block 53) (2.00%)(g)\nQatar\t1936\tAl Khalij (100.00%)\t\n\t\t\tNorth Field - Block NF Dolphin (24.50%)\n\t\t\tNorth Field - Block NFB (20.00%)\n\t\t\tNorth Field -Qatargas 2 Train 5 (16.70%)\nSyria\t1988\tDeir Ez Zor (Al Mazraa Atalla North Jafra Marad Qahar Tabiyeh) (100.00%)(h)\t\nYemen\t1987\tKharir/Atuf (bloc 10) (28.57%)\t\n\t\t\tVarious fields onshore (Block 5) (15.00%)\n", "q10k_tbl_15": "(a)\tThe Group's interest in the local entity is approximately 100% in all cases except for Total Gabon (58.3%) Total E&P Cameroon (75.80%) and certain entities in the United Kingdom Algeria Abu Dhabi and Oman (see notes b through i below).\n(b)\tTOTAL has an indirect 19.41% interest in the Ourhoud field and a 48.83% indirect interest in the RKF field through its interest in CEPSA (equity affiliate).\n(c)\tTOTAL has a 35.8% indirect interest in Elgin Franklin through its interest in EFOG.\n(d)\tThrough ADMA (equity affiliate) TOTAL has a 13.33% interest and participates in the operating company Abu Dhabi Marine Operating Company.\n(e)\tThrough ADPC (equity affiliate) TOTAL has a 9.50% interest and participates in the operating company Abu Dhabi Company for Onshore Oil Operation.\n(f)\tTOTAL has a direct interest of 4.00% in Petroleum Development Oman LLC operator of Block 6 in which TOTAL has an indirect interest of 4.00% via Pohol (equity affiliate). 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).\n(g)\tTOTAL has a direct interest of 2.00% in Block 53.\n(h)\tOperated by DEZPC which is 50.00% owned by TOTAL and 50.00% owned by SPC.\n(i)\tTOTAL has an indirect 34.18% interest in the Caracara Block 8.14% in the San Jacinto/Rio Paez Block and 7.32% in the Espinal Block through its interest in CEPSA (equity affiliate).\n", "q10k_tbl_16": "0\tBasic engineering studies for the Timimoun project were launched in 2010 following approval by the ALNAFT national agency. Start-up of the project is scheduled in 2014 with commercial production of natural gas estimated at approximately 160 Mcf/d (1.6 Bm3/y) at plateau.\n0\tAs part of the Ahnet project a development plan is expected to be submitted to the authorities before mid-2011 with start-up of production scheduled for 2015 and an expected plateau production of at least 400 Mcf/d (4 Bm3/y).\n", "q10k_tbl_17": "0\tOn Block 14 (20%) production on the Tombua-Landana field started in August 2009 and adds to production from the Benguela-Belize-Lobito-Tomboco and Kuito fields.\n0\tOn ultra-deep offshore Block 32 (30% operator) appraisal is continuing and pre-development studies for a first production zone in the central/southeastern portion of the block are underway (Kaombo project).\n0\tOn Block 15/6 (15%) four major discoveries were announced in 2010. Studies are underway to demonstrate the feasibility of a first development area that would include the discoveries located on the northwest portion of the block.\n", "q10k_tbl_18": "0\tOn the deep-offshore Diaba license (Total Gabon 63.75% operator) following the 2D seismic survey that was shot in 2008 and 2009 a 6000 km2 3D seismic was shot in 2010.\n0\tLicenses for the Avocette and Coucal fields have been renewed in the form of an operating and production sharing agreement effective as of January 1 2011 each for a 10-year period renewable for two subsequent 5-year periods.\n0\tTotal Gabon farmed into the onshore Mutamba-Iroru (50%) DE7 (30%) and Nziembou (20%) exploration licenses in 2010.\n", "q10k_tbl_19": "0\tOn Block C 137 drilling of two offshore exploration wells is planned for 2011.\n0\tOn Blocks NC 115 and NC 186 the nearly 5000 km2 seismic campaign is expected to be completed in 2011.\n0\tOn the Murzuk Basin following a successful appraisal well drilled on the discovery made on a portion of Block NC 191 (100%(2) operator) a development plan was submitted to the authorities in 2009.\n0\tIn December 2010 the Group relinquished Block 42 2/4 (60%(2) operator) located in the Cyrenaic Basin at the contract expiration date following an exploration well's disappointing results.\n", "q10k_tbl_20": "0\tOn the OML 136 license (40%) the positive results for the Agge 3 appraisal well confirmed the development potential of the license. Development studies are underway.\n0\tAs part of its joint venture with the Nigerian National Petroleum Corporation (NNPC) TOTAL launched a project to increase the production capacity of the OML 58 license (40% operator) from 370 Mcf/d to 550 Mcf/d of gas in 2011. A second phase of this project which is currently being assessed is expected to allow the development of other reserves through these facilities.\n0\tOn the OML 112/117 licenses (40%) TOTAL continued development studies in 2010 for the Ima gas field.\n", "q10k_tbl_21": "0\tOn the OML 102 license (40% operator) TOTAL is expected to make the final investment decision for the Ofon phase 2 project in 2011 with a start-up scheduled in 2014. The Group also launched in 2010 an appraisal campaign for the Etisong field located 15 km from the Ofon field which is currently producing.\n0\tOn the OML 130 license (24% operator) the Akpo field which started up in March 2009 reached in 2010 plateau production of 225 kboe/d (in 100%). The Group is actively developing the Egina field for which a development plan was approved by the Nigerian authorities. Basic engineering studies carried out in Nigeria are now completed and call for tenders for the projects have been launched.\n0\tOn the OML 138 license (20% operator) development of the Usan project (180 kb/d production capacity) continued in 2010 in particular with the drilling of production wells the construction of the FPSO and the start of the installation of sub-sea equipment. Production is expected to start-up in 2012.\n0\tTOTAL also consolidated deep offshore positions with the ongoing development of the Bonga Northwest project on the OML 118 license (12.5%).\n", "q10k_tbl_22": "0\tOn the Moho Bilondo field (53.5% operator) which started up in April 2008 drilling of development wells continued in 2010. The field reached plateau production of 90 kboe/d (in 100%) in June 2010. Growth potential of the northern part of the field was confirmed by the Moho North Marine 3 appraisal well drilled at year-end 2008 following the Moho North Marine 1 and 2 discoveries and later in 2009 by the Moho North Marine 4 exploration well that discovered new resources. Finally two positive appraisal wells (Bilondo Marine 2 & 3) drilled at year-end 2010 in the southern portion of the field confirmed an additional growth potential as an extension of existing facilities.\n0\tProduction on Libondo (65% operator) which is part of the Kombi-Likalala-Libondo operating license started up in March 2011. Anticipated plateau production is 8 kb/d (in 100%). A substantial portion of the equipment was sourced locally in Pointe-Noire through the redevelopment of a construction site that had been idle for several years.\n", "q10k_tbl_23": "\tConstruction work for phases 1B and 1C was completed which should allow these phases to reach production level estimated at 24 kb/d (in 100%). The wells of phase 1B gradually started production in 2009 and 2010 and those of phase 1C are expected to be connected and to start production in 2011.\n\tIn early 2010 the partners of the project decided to launch the construction of the second phase of development. Start-up of production from Surmont Phase 2 is scheduled in 2015 and overall production capacity from Surmont (phases 1 and 2) is expected to increase to 110 kb/d (in 100%).\n0\tThe Joslyn lease located approximately 140 km north of Surmont is expected to be developed through mining in two phases of 100 kb/d of bitumen each.\n\tThe comprehensive review of the first phase (Joslyn North Mine) notably to meet the requirements of the February 2009 new regulation related to tailings management was completed in February 2010 concurrent with the filing of an updated administrative file. Continuation of the preparation work for Joslyn North Mine was approved in early March 2010 and basic engineering studies were launched that are expected to end in mid-2011. Public hearings that are necessary for the project to be approved by the Canadian authorities were held in September and October 2010. The project was recommended as being in the public's interest on January 27 2011 subject to TOTAL satisfying twenty conditions mainly related to the protection of the environment. Preliminary site preparation work is expected to be carried out from the winter 2011-2012 and production is scheduled to start in 2017/2018. However the final schedule is subject to the Energy Resources Conservation Board's (ERCB) administrative approval process. As part of the partnership agreement signed at year-end 2010 with Suncor the Group decreased its interest in Joslyn to 38.25% from 75%.\n0\tTOTAL closed in September 2010 the acquisition of UTS and its sole asset: a 20% interest in the Fort Hills lease. In December 2010 as part of their partnership TOTAL acquired from Suncor an additional 19.2% interest in the Fort Hills lease and increased its interest to 39.2%. Start-up of the Fort Hills project which was approved by the relevant authorities for a first development phase of 160 kb/d is expected in 2016.\n0\tTOTAL also acquired in late December 2010 a 49% interest in Suncor's Voyageur upgrader project. TOTAL and Suncor agreed to develop the Fort Hills and Voyageur projects in parallel. This Voyageur upgrader project that Suncor mothballed at year-end 2008 will resume in 2011 and will start up concurrently with the Fort Hills project. As a consequence the Group has abandoned its upgrader project in Edmonton.\n0\tIn 2008 the Group closed the acquisition of Synenco the two principal assets of which are a 60% interest in the Northern Lights project and 100% of the adjacent McClelland lease. In early 2009 the Group sold to Sinopec the other partner in the project a 10% share in the Northern Lights project and a 50% share in the McClelland lease reducing its interest in each of the assets to 50%. The Northern Lights project located approximately 50 km north of Joslyn is expected to be developed through mining techniques.\n", "q10k_tbl_24": "0\tThe deep-offshore Tahiti oil field (17%) started producing in May 2009 and rapidly reached plateau production of 135 kboe/d. Phase 2 was launched in September 2010 with the drilling of the first water injection well.\n0\tDevelopment of the first phase of the deep-offshore Chinook project (33.33%) is ongoing. The production test is scheduled to start in the first half of 2011.\n0\tThe TOTAL (40%) - Cobalt (60% operator) alliance's exploration drilling campaign was\n", "q10k_tbl_25": "0\tFollowing the signature of an agreement in December 2009 a joint venture was set up with Chesapeake to produce shale gas in the Barnett Shale Basin Texas. As part of this joint venture TOTAL holds 25% of Chesapeake's portfolio in the Barnett Shale area. In 2010 400 wells were drilled to increase gas production from 700 Mcf/d at the beginning of the year to 800 Mcf/d at year-end. Engineers from TOTAL are assigned to the teams led by Chesapeake.\n0\tIn January 2009 the Group closed the acquisition of a 50% interest in American Shale Oil LLC (AMSO) to develop oil shale technology. The pilot to develop this technology is underway in Colorado.\n0\tIn Alaska TOTAL acquired in 2008 a 30% interest in several onshore exploration blocks known as \"White Hills\". Most of them were relinquished in mid-2009 following disappointing results.\n", "q10k_tbl_26": "0\tProduction started up in February 2011 on the gas and condensates Itaú field located on Block XX Tarija Oeste; it is routed to the existing facilities of the neighboring San Alberto field. In 2010 TOTAL decreased its interest to 41% in Block XX Tarija Oeste after divesting 34% and is no longer the operator.\n0\tIn 2004 TOTAL discovered the Incahuasi gas field on the Ipati Block. Following the interpretation of the 3D seismic shot in 2008 an appraisal well is ongoing on the adjacent Aquio Block to confirm the extension of the discovery to the north. In 2010 TOTAL signed an agreement to dispose of 20% in the Aquio and Ipati licenses. Under this agreement which is subject to the approval by the Bolivian authorities TOTAL's interest in the licenses will be 60%.\n", "q10k_tbl_27": "0\tOn Block BC-2 following seismic reprocessing a pre-salt prospect was found under the Xerelete (formerly Curió) discovery made in 2001 at a water depth of 2400 m.\n0\tThe southern extremity of Xelerete is located on Block BM-C-14 which is adjacent to Block BC-2. A unitization agreement was completed by the partners on both blocks. This agreement is subject to approval by the ANP (Agência National do Petroléo).\n0\tIn June 2010 the Group acquired a 20% interest in the BM-S-54 license. Preliminary assessment of data from the exploration drilling which was completed in November 2010 was positive and a second drilling is expected in 2011.\n", "q10k_tbl_28": "0\tPursuant to the decision by the Venezuelan authorities to terminate all operating contracts signed in the 1990s the Sincor association in which TOTAL held an interest was transformed into a mixed public/private company: PetroCedeño. Under this agreement that led to the transfer of operatorship to PetroCedeño TOTAL's interest in the project decreased from 47% to 30.323% and PDVSA's interest increased to 60%. The transformation process was completed in February 2008.\n\tPDVSA agreed to compensate TOTAL for the reduction of its interest in Sincor by assuming $326 million of debt and by paying mostly in crude oil $834 million. The compensation process was completed in 2009.\n0\tOn Block 4 the exploration campaign which involved three wells was completed in 2007. In 2008 the authorities agreed to let the partners retain the Cocuina discovery zone (lots B and F) and relinquish the rest of the block.\n0\tIn early 2008 TOTAL signed two agreements for joint studies with PDVSA on the Junin 10 Block in the Orinoco Belt.\n", "q10k_tbl_29": "0\tFEED studies for the development of the gas and condensates Ichthys field located in the Browse Basin are ongoing. The studies launched in 2009 include a floating platform designed for gas production treatment and export an FPSO to stabilize and export condensates an 885 km gas pipeline and a liquefaction plant located in Darwin.\n\tProduction capacity is expected to be 8.4 Mt/y of LNG and 1.6 Mt/y of LPG as well as production capacity of 100 kb/d of condensates. The operator plans a start-up of the field at year-end 2016.\n0\tIn late 2010 TOTAL acquired a 20% interest in the GLNG project followed by an additional 7.5% interest for which the acquisition was closed in March 2011. This integrated gas production transport and liquefaction project is based on the development of coal gas from the Fairview Roma Scotia and Arcadia fields. The final investment decision was made in January 2011 and start-up is expected in 2015. LNG production is expected to eventually reach 7.2 Mt/y.\n0\tMajor seismic acquisition activity occurred in 2008 on the four exploration licenses operated by TOTAL followed by the interpretation of data in 2009. A drilling campaign involving two wells started in early 2011 on the WA403 license (60% operator).\n0\tIn 2010 following unsuccessful results TOTAL relinquished the exploration licenses located in the Carnarvon Basin.\n", "q10k_tbl_30": "0\tOn Peciko following the start-up of a new platform (phase 5) in late 2008 a new phase of drilling operations (phase 7) started in 2009 and continued in 2010. New low-pressure compression capacities (phase 6) were commissioned in May 2010.\n0\tOn Bekapai debottlenecking operations to increase gas production were completed in July 2010.\n0\tDevelopment of the South Mahakam permit continued with the award of the Engineering Procurement and Construction contract (EPC) in August 2010 to develop the Stupa West Stupa and East Mandu discoveries. Start-up of production is expected in early 2013.\n", "q10k_tbl_31": "0\tOn the Sisi-Nubi field which began production in 2007 drilling operations continue. The gas from Sisi-Nubi is produced through Tunu's processing facilities.\n0\tIn 2008 a seismic campaign was conducted on the Southeast Mahakam exploration block (50% operator) located in the Mahakam Delta. Drilling of the first exploration well (Trekulu 1) was completed in late 2010.\n0\tIn May 2010 the Group acquired a 24.5% interest in two exploration blocks - Arafura and Amborip VI - located in the Arafura sea. Drilling of a first well started in mid-November 2010 on the Amborip VI license which was followed by a second drilling that started in early 2011 on the Arafura license.\n0\tIn October 2010 the Group closed the acquisition of a 15% interest in the Sebuku license where the Ruby gas discovery is located the development of which was launched in mid-February 2011 with targeted production of 100 Mcf/d of natural gas and expected start-up in 2013.\n", "q10k_tbl_32": "0\tGas deliveries to Turkey and Georgia from the Shah Deniz field continued throughout 2010 at a lower pace for Turkey due to weaker demand. In 2010 SOCAR the Azerbaijan state-owned company took gas quantities superior to those provided for by the agreement.\n\tAn agreement was made with Botas a Turkish state-owned company to revise the price of gas sold to Turkey as part of Shah Deniz Phase 1 applicable with retroactive effect from April 15 2008.\n\tDevelopment studies and business negotiations for the sale of additional gas needed to launch a second development phase in Shah Deniz continued in 2010. SOCAR and Botas signed in June 2010 a Memorandum of Understanding for the sale of additional gas volumes and the transfer conditions for volumes intended for the European market. This agreement is expected to allow FEED studies to start in 2011 for the second phase.\n0\tOn the BTC oil pipeline notably used to transport the condensates produced at Shah Deniz equipment was installed in 2009 to inject additives to reduce drag. This resulted in the oil pipeline capacity increasing from 1 Mb/d to 1.2 Mb/d.\n", "q10k_tbl_33": "0\tIn December 2009 TOTAL closed the acquisition from Novatek of a 49% interest in Terneftegas which holds a development and production license on the onshore Termokarstovoye field. An appraisal well was drilled in 2010 the results of which are expected to lead to a final investment decision by year-end 2011.\n0\tOn the Kharyaga field work related to the development plan of phase 3 is ongoing. This development plan is intended to maintain plateau production at the 30 kboe/d (in 100%) level reached in late 2009. In December 2009 TOTAL signed an agreement effective January 1 2010 to sell 10% of the field to state-owned Zarubezhneft and decreased its interest to 40%.\n0\tIn October 2009 TOTAL signed an agreement setting forth the principles of a partnership with KazMunaiGas (KMG) for the development of the Khvalynskoye gas and condensates field located offshore in the Caspian Sea on the border between Kazakhstan and Russia under Russian jurisdiction. Gas production is expected to be transported to Russia. Pursuant to this agreement TOTAL is planning to acquire a 17% interest in KMG's share.\n0\tOn March 2 2011 TOTAL and Novatek signed two agreements in principle providing for:\n", "q10k_tbl_34": "0\tTOTAL becoming the main international partner on the Yamal LNG project with a 20% interest and Novatek holding a 51% interest in the project. As part of the agreement the transaction is expected to be closed by July 2011.\n0\tTOTAL taking a 12.08% interest in Novatek with both parties intending that TOTAL increases its interest to 15% within 12 months and to 19.40% within 36 months.\n", "q10k_tbl_35": "0\tSeveral projects are ongoing or are under study in the Greater Ekofisk Area where the Group has a 39.9% participation in the Ekofisk and Eldfisk fields. The Ekofisk South and Eldfisk 2 projects are expected to be launched in 2011 after receiving the approval from the Norwegian authorities.\n0\tIn 2010 the Group sold its interests in the Valhall/Hod fields.\n0\tOn the Greater Hild Area the Group holds a 49% interest (operator). The development scheme was selected at year-end 2010. The project is expected to be approved in 2011 and production is scheduled to start up in 2016.\n0\tOn Frigg decommissioning is completed.\n", "q10k_tbl_36": "0\tIn the Norwegian Sea the Haltenbanken area includes the Tyrihans (23.2%) Mikkel (7.7%) and Kristin (6%) fields as well as the Åsgard (7.7%) field and its satellites Yttergryta (24.5%) and Morvin (6%). Morvin started up in August 2010 as planned with two producing wells. In 2010 the Group's production in the Haltenbanken area was 61 kboe/d.\n0\tIn the Barents Sea LNG production on Snøhvit (18.4%) started in 2007. This project includes development of the natural gas fields Snøhvit Albatross and Askeladd as well as the construction of the associated liquefaction facilities. Due to design problems the plant experienced reduced capacity during the start-up phase. A number of maintenance turnarounds were scheduled to fix the issue and the plant is now operating at its design capacity (4.2 Mt/y).\n", "q10k_tbl_37": "0\tOn the K5F field (40.39% operator) production began in 2008. This project is comprised of two sub-sea wells connected to the existing production and transport facilities. K5F is the first project in the world to use only electrically driven sub-sea well heads and systems.\n0\tDevelopment of the K5CU project (49% operator) was launched in 2009 and production started up in early 2011. This development includes four wells supported by a platform that has been installed in September 2010 and is connected to the K5A platform by a 15 km gas pipeline.\n", "q10k_tbl_38": "0\tOn the Alwyn zone start-up of satellite fields or new reservoir compartments allowed production to be maintained. The processing and compressing capacities of the Alwyn platform increased from 530 Mcf/d to 575 Mcf/d during the summer of 2008 planned shutdown for maintenance.\n\tThe N52 well drilled on Alwyn (100%) in a new compartment of the Statfjord reservoir came onstream in February 2010 with initial flow of 15 kboe/d (gas and condensates).\n", "q10k_tbl_39": "As of December 31\t\t2010\t\t2009\t\t2008\t\n(in thousand of acres at\t\tUndeveloped\tDeveloped\tUndeveloped\tDeveloped\tUndeveloped\tDeveloped\nyear-end)\t\tacreage(a)\tacreage\tacreage(a)\tacreage\tacreage(a)\tacreage\nEurope\tGross\t6802\t776\t5964\t667\t5880\t647\n\tNet\t3934\t184\t2203\t182\t2191\t181\nAfrica\tGross\t72639\t1229\t85317\t1137\t85883\t1112\n\tNet\t33434\t349\t45819\t308\t41608\t292\nAmericas\tGross\t16816\t1022\t9834\t776\t8749\t484\n\tNet\t5755\t319\t4149\t259\t4133\t186\nMiddle East\tGross\t29911\t1396\t33223\t204\t33223\t199\n\tNet\t2324\t209\t2415\t97\t2415\t69\nAsia\tGross\t36519\t539\t29609\t397\t25778\t387\n\tNet\t17743\t184\t16846\t169\t12529\t131\nTotal\tGross\t162687\t4962\t163947\t3181\t159513\t2829\n\tNet(b)\t63190\t1245\t71432\t1015\t62876\t859\n", "q10k_tbl_40": "As of December 31\t\t2010\t\t2009\t\t2008\t\n\t\tGross\tNet\tGross\tNet\tGross\tNet\n\t\tproductive\tproductive\tproductive\tproductive\tproductive\tproductive\n(number of wells at year-end)\t\twells\twells(a)\twells\twells(a)\twells\twells(a)\nEurope\tLiquids\t569\t151\t705\t166\t700\t166\n\tGas\t368\t132\t328\t125\t328\t127\nAfrica\tLiquids\t2250\t628\t2371\t669\t2465\t692\n\tGas\t182\t50\t190\t50\t112\t34\nAmericas\tLiquids\t884\t261\t821\t241\t621\t176\n\tGas\t2532\t515\t1905\t424\t254\t79\nMiddle East\tLiquids\t7519\t701\t3766\t307\t3762\t264\n\tGas\t360\t49\t136\t32\t83\t15\nAsia\tLiquids\t196\t75\t157\t75\t184\t68\n\tGas\t1258\t411\t1156\t379\t1049\t271\nTotal\tLiquids\t11418\t1816\t7820\t1458\t7732\t1366\n\tGas\t4700\t1157\t3715\t1010\t1826\t526\n", "q10k_tbl_41": "As of December 31\t\t2010\t\t\t2009\t\t\t2008\t\t\n\t\tNet\t\t\tNet\t\t\tNet\t\t\n\t\tproductive\tNet dry\tTotal\tproductive\tNet dry\tTotal\tproductive\tNet dry\tTotal\n\t\twells\twells\tnet wells\twells\twells\tnet wells\twells\twells\tnet wells\n\t\tdrilled(a)\tdrilled(a)\tdrilled(a)\tdrilled(a)\tdrilled(a)\tdrilled(a)\tdrilled(a)\tdrilled(a)\tdrilled(a)\nExploratory(b)\tEurope\t1.7\t0.2\t1.9\t0.4\t3.7\t4.1\t1.3\t2.0\t3.3\n\tAfrica\t1.6\t4.3\t5.9\t5.9\t3.2\t9.1\t4.7\t3.2\t7.9\n\tAmericas\t1.0\t1.6\t2.6\t0.8\t1.6\t2.4\t0\t2.6\t2.6\n\tMiddle East\t0.9\t0.3\t1.2\t0.3\t0\t0.3\t0.4\t0\t0.4\n\tAsia\t3.2\t1.2\t4.4\t1.7\t1.2\t2.9\t4.1\t2.2\t6.3\n\tSubtotal\t8.4\t7.6\t16.0\t9.1\t9.7\t18.8\t10.5\t10.0\t20.5\nDevelopment\tEurope\t5.0\t0\t5.0\t5.0\t0\t5.0\t6.2\t0\t6.2\n\tAfrica\t18.1\t0\t18.1\t27.5\t0.2\t27.7\t38.3\t6.4\t44.7\n\tAmericas\t135.3\t112.5\t247.8\t31.2\t104.3\t135.5\t41.5\t270.9\t312.4\n\tMiddle East\t29.6\t1.4\t31.0\t42.6\t3.4\t49.0\t61.2\t7.6\t68.8\n\tAsia\t59.3\t0\t59.3\t63.5\t0.3\t63.8\t58.7\t0\t58.7\n\tSubtotal\t247.3\t113.9\t361.2\t172.8\t108.2\t281.0\t205.9\t284.9\t490.8\nTotal\t\t255.7\t121.5\t377.2\t181.9\t117.9\t299.8\t216.4\t294.9\t511.3\n", "q10k_tbl_42": "As of December 31\t\t2010\t\t2009\t\t2008\t\n(number of wells at year-end)\t\tGross\tNet(a)\tGross\tNet(a)\tGross\tNet(a)\nExploratory\tEurope\t3\t2.1\t1\t0.5\t2\t1.1\n\tAfrica\t4\t1.4\t4\t1.3\t7\t2.5\n\tAmericas\t2\t0.9\t2\t0.6\t1\t0.5\n\tMiddle East\t2\t1.2\t1\t0.4\t1\t0.3\n\tAsia\t2\t1.1\t0\t0\t1\t0.1\n\tSubtotal\t13\t6.7\t8\t2.8\t12\t4.5\nDevelopment\tEurope\t21\t3.8\t5\t2.2\t7\t3.7\n\tAfrica\t29\t6.4\t31\t8.5\t19\t4.3\n\tAmericas\t99\t29.2\t60\t17.8\t9\t3.2\n\tMiddle East\t20\t5.1\t40\t4.8\t5\t2.2\n\tAsia\t23\t9.8\t12\t5.5\t23\t7.8\n\tSubtotal\t192\t54.3\t148\t38.8\t63\t21.2\nTotal\t\t205\t61.0\t156\t41.6\t75\t25.7\n", "q10k_tbl_43": "\t\t\t%\t\t\t\t\nPipeline(s)\tOrigin\tDestination\tinterest\t\tOperator\tLiquids\tGas\nEUROPE\t\t\t\t\t\t\t\nFrance\t\t\t\t\t\t\t\nTIGF\tNetwork South West\t\t100.00\t\tx\t\tx\nNorway\t\t\t\t\t\t\t\nFrostpipe (inhibited)\tLille-Frigg Froy\tOseberg\t36.25\t\t\tx\t\nGassled(a)\t\t\t7.76\t\t\t\tx\nHeimdal to Brae Condensate Line\tHeimdal\tBrae\t16.76\t\t\tx\t\nKvitebjorn pipeline\tKvitebjorn\tMongstad\t5.00\t\t\tx\t\nNorpipe Oil\tEkofisk Treatment center\tTeeside (UK)\t34.93\t\t\tx\t\nOseberg Transport System\tOseberg Brage and Veslefrikk\tSture\t8.65\t\t\tx\t\nSleipner East Condensate Pipe\tSleipner East\tKarsto\t10.00\t\t\tx\t\nTroll Oil Pipeline I and II\tTroll B and C\tVestprosess (Mongstad refinery)\t3.71\t\t\tx\t\nThe Netherlands\t\t\t\t\t\t\t\nNogat pipeline\tF3-FB\tDen Helder\t5.00\t\t\t\tx\nWGT K13-Den Helder\tK13A\tDen Helder\t4.66\t\t\t\tx\nWGT K13-Extension\tMarkham\tK13 (via K4/K5)\t23.00\t\t\t\tx\nUnited Kingdom\t\t\t\t\t\t\t\nAlwyn Liquid Export Line\tAlwyn North\tCormorant\t100.00\t\tx\tx\t\nBruce Liquid Export Line\tBruce\tForties (Unity)\t43.25\t\t\tx\t\nCentral Area Transmission System (CATS)\tCats Riser Platform\tTeeside\t0.57\t\t\t\tx\nCentral Graben Liquid Export Line (LEP)\tElgin-Franklin\tETAP\t15.89\t\t\tx\t\nFrigg System : UK line\tAlwyn North Bruce and others\tSt.Fergus (Scotland)\t100.00\t\tx\t\tx\nNinian Pipeline System\tNinian\tSullom Voe\t16.00\t\t\tx\t\nShearwater Elgin Area Line (SEAL)\tElgin-Franklin Shearwater\tBacton\t25.73\t\t\t\tx\nSEAL to Interconnector Link (SILK)\tBacton\tInterconnector\t54.66\t\tx\t\tx\nAFRICA\t\t\t\t\t\t\t\nAlgeria\t\t\t\t\t\t\t\nMedgaz\tAlgeria\tSpain\t9.77\t(b)\t\t\tx\nGabon\t\t\t\t\t\t\t\nMandji Pipes\tMandji fields\tCap Lopez Terminal\t100.00\t(c)\tx\tx\t\nRabi Pipes\tRabi fields\tCap Lopez Terminal\t100.00\t(c)\tx\tx\t\nAMERICAS\t\t\t\t\t\t\t\nArgentina\t\t\t\t\t\t\t\nGas Andes\tNeuquen Basin (Argentina)\tSantiago (Chile)\t56.50\t\tx\t\tx\nTGN\tNetwork (Northern Argentina)\t\t15.40\t\tx\t\tx\nTGM\tTGN\tUruguyana (Brazil)\t32.68\t\tx\t\tx\nBolivia\t\t\t\t\t\t\t\nTransierra\tYacuiba (Bolivia)\tRio Grande (Bolivia)\t11.00\t\t\t\tx\nBrazil\t\t\t\t\t\t\t\nTBG\tBolivia-Brazil border\tPorto Alegre via São Paulo\t9.67\t\t\t\tx\nColombia\t\t\t\t\t\t\t\nOcensa\tCusiana\tCovenas Terminal\t15.20\t\t\tx\t\nOleoducto de Alta Magdalena\tTenay\tVasconia\t0.93\t\t\tx\t\nOleoducto de Colombia\tVasconia\tCovenas\t9.55\t\t\tx\t\nASIA\t\t\t\t\t\t\t\nYadana\tYadana (Myanmar)\tBan-I Tong (Thai border)\t31.24\t\tx\t\tx\nREST OF WORLD\t\t\t\t\t\t\t\nBTC\tBaku (Azerbaijan)\tCeyhan (Turkey Mediterranean)\t5.00\t\t\tx\t\nSCP\tBaku (Azerbaijan)\tGeorgia/Turkey Border\t10.00\t\t\t\tx\nDolphin (International transport and network)\tRas Laffan (Qatar)\tU.A.E.\t24.50\t\t\t\tx\n", "q10k_tbl_44": "0\tThe Afam VI project part of the SPDC (Shell Petroleum Development Company) joint venture in which TOTAL holds a 10% interest concerns the development of a 630 MW combined-cycle power plant. Commercial operations started in December 2010.\n0\tThe development of a new 400 MW combined-cycle power plant near the city of Obite (Niger Delta) in connection with the OML 58 gas project part of the joint venture between NNPC and TOTAL (40% operator). A final investment decision is expected in the first half of 2011 and commissioning is scheduled in the first half of 2013 in open cycle and in early 2014 in closed cycle. The power plant will be connected to the existing power grid through a new 108 km high-voltage transmission line.\n", "q10k_tbl_45": "0\tIn the United Kingdom commissioning of the hydrodesulphurization (HDS) unit at the Lindsey refinery is expected in the first half of 2011. This will result in processing up to 70% of high-sulphur crudes compared to 10% currently and increase low-sulphur diesel production. In parallel TOTAL announced that it offered for sale the Lindsey refinery in 2010.\n0\tIn Germany the HDS unit that started up in September 2009 at the Leuna refinery was operated successfully in 2010. This unit is designed to supply the German market with low-sulphur heating oil.\n", "q10k_tbl_46": "0\tIn Italy TotalErg (TOTAL 49%) has operated the Rome refinery (100%) since October 2010 and holds a 25.9% interest in the Trecate refinery.\n0\tIn Spain CEPSA completed its investments intended to improve the conversion capacity of the Huelva refinery so as to meet the growing demand for middle distillates in the Spanish market. A hydrocracker unit two additional distillation units (one atmospheric and one vacuum) and a desulphurization unit were inaugurated in October 2010. Distillation capacity increased to 178 kb/d from 100 kb/d. In February 2011 the Group announced the signature of an agreement with IPIC to dispose of its 48.83% interest in CEPSA. The transaction is conditioned on obtaining all requisite approvals.\n", "q10k_tbl_47": "0\tIn the United States TOTAL operates the Port Arthur refinery in Texas with a capacity of 174 kb/d. In 2008 TOTAL launched a modernization program that includes the construction of a desulphurization unit commissioned in July 2010 a vacuum distillation unit a deep-conversion unit (or coker) and other associated units. This project is designed to process more heavy and high-sulphur crudes and to increase production of lighter products in particular low-sulphur distillates. Construction is completed and commissioning was ongoing in March 2011.\n0\tIn Saudi Arabia TOTAL and Saudi Arabian Oil Company (Saudi Aramco) created a joint venture in September 2008 Saudi Aramco Total Refining and Petrochemical Company (SATORP) to build a 400 kb/d refinery in Jubail held by Saudi Aramco (62.5%) and TOTAL (37.5%). TOTAL and Saudi Aramco each plans to retain a 37.5% interest with the remaining 25% expected to be listed on the Saudi stock exchange subject to approval by the relevant authorities. The main contracts for the construction of the refinery were signed in July 2009 concurrent with the start-up of work. Commissioning is expected in 2013.\n\tThe heavy conversion process of this refinery is designed for processing heavier crudes (Arabian Heavy) and producing fuels and lighter products that meet strict specifications and are mainly intended for export.\n0\tIn Africa the Group holds minority interests in five refineries in South Africa Senegal Côte d'Ivoire Cameroon and Gabon.\n", "q10k_tbl_48": "As of December 31 (kb/d)\t2010\t2009\t2008\nRefineries operated by the Group\t\t\t\nNormandy (France)\t199\t338\t339\nProvence (France)\t158\t158\t158\nFlanders (France)\t0\t137\t137\nDonges (France)\t230\t230\t230\nFeyzin (France)\t117\t117\t117\nGrandpuits (France)\t101\t101\t101\nAntwerp (Belgium)\t350\t350\t350\nLeuna (Germany)\t230\t230\t230\nRome (Italy)(b)\t0\t64\t64\nLindsey - Immingham (United Kingdom)\t221\t221\t221\nVlissingen (Netherlands)(c)\t81\t81\t81\nPort Arthur Texas (United States)\t174\t174\t174\nSub-total\t1861\t2201\t2202\nOther refineries in which the Group has an interest(d)\t502\t393\t402\nTotal\t2363\t2594\t2604\n", "q10k_tbl_49": "(a)\tFor refineries not 100% owned by TOTAL the indicated capacity represents TOTAL's share of the site's overall refining capacity.\n(b)\tTOTAL's interest was 71.9% until September 30 2010.\n(c)\tTOTAL's interest is 55%.\n(d)\tTOTAL has interests ranging from 12% to 50% in fourteen refineries (five in Africa four in Spain two in Italy one in Germany one in Martinique and one in China). Since October 1 2010 including the Group's share in the Rome and Trecate refineries through its interest in TotalErg. TOTAL disposed of its 50% interest in the Indeni refinery in Zambia in 2009.\n", "q10k_tbl_50": "(kb/d)\t2010\t2009\t2008\nGasoline\t345\t407\t443\nAvgas and jet fuel(b)\t168\t186\t208\nDiesel and heating oils\t775\t851\t987\nHeavy fuels\t233\t245\t257\nOther products\t359\t399\t417\nTotal\t1880\t2088\t2312\n", "q10k_tbl_51": "\t2010\t2009\t2008\nOn crude and other feedstock(a)(b)\t\t\t\nFrance\t64%\t77%\t89%\nRest of Europe\t85%\t88%\t93%\nAmericas\t83%\t77%\t88%\nAsia\t81%\t80%\t76%\nAfrica\t76%\t77%\t79%\nNet share of CEPSA and TotalErg(c)\t94%\t93%\t106%\nAverage\t77%\t83%\t91%\n", "q10k_tbl_52": "0\tIn Italy TotalErg was created in October 2010 and became the third largest marketer with a network market share of nearly 13%(5) and more than 3200 service stations.\n0\tIn France TOTAL started to implement the project to adapt oil logistics operations in January 2010. Closure of the Pontet and Saint Julien oil depots is ongoing. Hauconcourt's operations were transferred to the Raffinerie du Midi company on October 1 2010. Transfer of the Mans oil depot's operations and divesting of the Ouistreham oil depot are scheduled in the first half of 2011.\n", "q10k_tbl_53": "(kb/d)\t2010\t2009\t2008\nFrance\t725\t808\t822\nEurope excluding France(a)\t1204\t1245\t1301\nUnited States\t65\t118\t147\nAfrica\t292\t281\t279\nRest of world\t209\t189\t171\nTotal excluding Trading\t2495\t2641\t2720\nTrading\t1281\t975\t938\nTotal including trading\t3776\t3616\t3658\n", "q10k_tbl_54": "As of December 31\t2010\t\t2009\t\t2008\nFrance\t4272\t(b)\t4606\t(b)\t4782\nCEPSA and TotalErg(c)\t4958\t\t1734\t\t1811\nEurope excl. France CEPSA and TotalErg\t2832\t\t4485\t\t4541\nAfrica\t3570\t\t3647\t\t3500\nRest of world\t1858\t\t1827\t\t1791\nTotal\t17490\t\t16299\t\t16425\n", "q10k_tbl_55": "(a)\tExcluding AS24-branded service stations.\n(b)\tOf which nearly 2100 TOTAL-branded service stations nearly 280 Elf-branded service stations and more than 1900 Elan-branded service stations.\n(c)\t1737 CEPSA-branded service stations and as from October 1 2010 3221 TotalErg-branded service stations.\n", "q10k_tbl_56": "For the year ended December 31 (kb/d)\t2010\t2009\t2008\nWorldwide liquids production\t1340\t1381\t1456\nPurchased by the Trading division from the Group's Exploration & Production division\t1044\t1054\t1102\nPurchased by the Trading division from external suppliers\t2084\t2351\t2495\nTotal of Trading division's supply(a)\t3128\t3405\t3597\nSales of Trading division to Group Refining & Marketing division\t1575\t1752\t1994\nSales of Trading division to external customers\t1553\t1653\t1603\nTotal of Trading division's sales(a)\t3128\t3405\t3597\n", "q10k_tbl_57": "\t\t\t2010\t2009\t2008\tmin 2010\t\tmax 2010\t\nBrent ICE - 1st Line(a)\t($)\t/b\t80.34\t62.73\t98.52\t69.55\t(May 18)\t94.75\t(Dec. 24)\nBrent ICE - 12th Line(b)\t($)\t/b\t84.61\t70.43\t102.19\t75.29\t(Jan. 29)\t95.15\t(Dec. 24)\nContango time structure (12th-1st)\t($)\t/b\t4.27\t7.70\t3.59\t(0.55)\t(Nov. 29)\t6.98\t(May 31)\nGasoil ICE - 1st Line(c)\t($)\t/t\t673.88\t522.20\t920.65\t567.25\t(Feb. 01)\t784.50\t(Dec. 16)\nVLCC Ras Tanura Chiba - BITR(c)\t($)\t/t\t13.41\t10.43\t24.09\t8.24\t(Oct. 01)\t23.66\t(Jan. 12)\n", "q10k_tbl_58": "\t2010\t\t\t\t2009\t2008\n\t\t\tAsia and\t\t\t\n\t\tNorth\tMiddle\t\t\t\n(in millions of tons)\tEurope\tAmerica\tEast(a)\tWorldwide\tWorldwide\tWorldwide\nOlefins(b)\t4695\t1195\t1300\t7190\t6895\t7285\nAromatics\t2500\t940\t755\t4195\t4195\t4360\nPolyethylene\t1180\t460\t500\t2140\t2040\t2035\nPolypropylene\t1335\t1150\t295\t2780\t2780\t2750\nStyrenics(c)\t1050\t1260\t640\t2950\t3090\t3220\n", "q10k_tbl_59": "0\tThe Integrated Pollution Prevention and Control Directive (\"IPPC\") provides for a cost/benefit framework used to comprehensively assess the environmental quality standards of and prior environmental impacts and potential additional emissions limits on large industrial plants including refineries and chemical sites. The Industrial Emission Directive (IED) adopted in 2010 is expected to replace in 2013 a number of existing industrial emission directives including the IPPC and the Large Combustion Plant Directive. It will progressively result in stricter emission limits on some of TOTAL's facilities by making compulsory certain rules described in BREFs (Best available techniques REFerence documents) some of which are dedicated to specific industrial sectors. Certain BREFs are already published and will be revised (e.g. refining) and others will have to be developed.\n0\tThe Air Quality Framework Directive and related directives on ambient air quality assessment and management among other things limit emissions for sulphur dioxide oxides of nitrogen particulate matter lead carbon monoxide benzene and ozone.\n0\tThe Sulphur Content Directive limits sulphur in diesel fuel to 0.1% (since January 2008) and limits sulphur in heavy fuel oil to 1% (since January 2003) with certain exceptions for combustion plants provided that local air quality standards are met.\n0\tThe Large Combustion Plant Directive effective since 2008 limits certain emissions including sulphur dioxide nitrogen oxides and particulates from large combustion plants. It will be partly replaced in 2013 by the IED (see above).\n0\tExisting Directives controlling and limiting exhaust emissions from cars and other motor vehicles are expected to continue to become more stringent over time. Since 2009 a maximum sulphur content of 10 ppm is mandatory throughout the European Union.\n0\tThe 1996 Major Hazards Directive (Seveso II) requires emergency planning public disclosure of emergency plans assessment of hazards and effective emergency management systems. A revision process has just begun.\n0\tThe Framework Directive on Waste Disposal is intended to ensure that waste is recovered or disposed of without endangering human health and without using processes or methods that could unduly harm the environment. Numerous related directives regulate specific categories of waste. In November 2008 the Framework Directive on Waste Disposal was partially modified by the Directive on Waste 2008/98 which features more precise definitions and stronger provisions. Transposition of this Directive in France occurred in December 2010.\n0\tA number of Maritime Safety Directives were passed in the wake of the Erika and Prestige spills. Those regulations found in the three Maritime Safety Packages require that tankers have double hulls and that ship owners acquire improved insurance coverage mandate improvements to traffic monitoring accident investigations and in-port vessel inspection (Port State Control) and further regulate organizations that inspect and confirm conformity to applicable regulations (Classification Societies). The last package will enter into force in 2012.\n0\tNumerous Directives impose water quality standards based on the various uses of inland and coastal waters including ground water by setting limits on the discharges of many dangerous substances and by imposing information gathering and reporting requirements.\n", "q10k_tbl_60": "0\tIn March 2004 the European Union adopted a Directive on Environmental Liability. This Directive was transposed into EU Member State national legislations in 2007 and 2008 and in France in August 2008. The Directive seeks to implement a strict liability approach for damage to water resources soils and protected species and habitats by authorized industrial activities.\n0\tDirectives implementing the Aarhus Convention concerning public information rights and certain public participation rights in a variety of activities affecting the environment were adopted in January and May 2003 respectively and implemented in most national EU legislations.\n0\tIn November 2008 the European Union adopted a Directive on the protection of the environment through criminal law that obliges EU Member States to provide for criminal penalties in respect of serious infringements of EC law. EU Member States were to have transposed this Directive into their national legislation by December 26 2010.\n0\tTOTAL's facilities in the EU are also subject to extensive workplace safety regulations initiated by the European Community and defined and promulgated by each Member State.\n0\tWith respect to the climate change issue numerous initiatives in the European Union are pending or currently being revised including:\n", "q10k_tbl_61": "0\tA 2003 Directive implementing the Kyoto Protocol within the European Union established an emissions trading scheme effective as of January 2005 for greenhouse gas (\"GHG\") emissions quotas. On the basis of this directive carbon dioxide emissions permits are then delivered. This trading scheme required Member States to prepare under the supervision of the EU Commission national allocation plans identifying a global amount of quotas to be shared and delivered for free by the governments to each industrial installation of specific sectors in particular the energy intensive installations that have to surrender quotas in respect to their annually verified carbon dioxide emissions. In accordance with the 2009 revision of the aforementioned directive a progressive quota auctioning mechanism is scheduled to be set up in 2013 together with transitional Community-wide rules for harmonized free allocation up to a level based on benchmarks for sectors exposed to international carbon leakage. When this system will be established TOTAL's industrial facilities may incur capital and operating costs to comply with such legislation including the partial acquisition of emissions allowances.\n0\tAt the UN summit in Copenhagen in December 2009 world leaders recognized the need to limit global temperature increases to two degrees Celsius above pre-industrial levels but did not approve an international agreement on climate change which could result in a future stringent reduction of GHG emissions in the European Union.\n0\tThe first period of the Kyoto Protocol is reaching an end in 2012. Although debates occurred at the 2009 UN Summit in Copenhagen no decision as to the follow-up was made. The Cancun UN conference at the end of 2010 reaffirmed the principles of Kyoto but did not result in the adoption of any new legally binding agreement with respect to the continuation of the Kyoto Protocol. The next conference is expected to be held in Durban in late 2011.\n", "q10k_tbl_62": "0\tThe Climate Action and Renewable Energy Package commits EU Member States to reduce overall emissions to at least 20% below 1990 levels by 2020 requires Member States to improve energy efficiency and increase renewable energy usage. These latter issues are expected to be further addressed in 2011 in a way likely to affect TOTAL's operations in the future.\n0\tThe 2009 Directive on Carbon Capture and Storage (CCS) was transposed in France in 2010. This legal framework forms the basis for developing CCS projects that are expected to serve as one of the most valuable solutions for the reduction of carbon dioxide emissions. Such regulations will have technical and financial impacts including on TOTAL's projects.\n0\tIn France the provisions of the 2010 financial bill establishing a carbon tax was deemed unconstitutional and referred back to the French government which did not make a new proposal. The provisions of the 2011 financial bill made subject to payment a minor part of GHG emission allowance delivery for 2011 and 2012 which was initially allocated for free in the national plan of 2008-2012.\n", "q10k_tbl_63": "As of and for the year ended December 31 (M€ except per share data)\t2010\t2009\t2008\nNon-Group sales\t159269\t131327\t179976\nNet income (Group share)\t10571\t8447\t10590\nDiluted earnings per share\t4.71\t3.78\t4.71\n", "q10k_tbl_64": "(M€)\t2010\t2009\t2008\nNon-Group sales\t18527\t16072\t24256\nOperating income(a)\t17450\t12858\t23468\nEquity in income (loss) of affiliates and other items\t1533\t846\t1541\nTax on net operating income\t(10131)\t(7486)\t(14563)\nNet operating income(a)\t8852\t6218\t10446\nAdjustments affecting net operating income\t(255)\t164\t278\nAdjusted net operating income(b)\t8597\t6382\t10724\nInvestments\t13208\t9855\t10017\nDivestments\t2067\t398\t1130\nROACE\t21%\t18%\t36%\n", "q10k_tbl_65": "(M€)\t2010\t2009\t2008\nNon-Group sales\t123245\t100518\t135524\nOperating income(a)\t982\t2237\t826\nEquity in income (loss) of affiliates and other items\t141\t169\t(158)\nTax on net operating income\t(201)\t(633)\t(143)\nNet operating income(a)\t922\t1773\t525\nAdjustments affecting net operating income\t246\t(820)\t2044\nAdjusted net operating income(b)\t1168\t953\t2569\nInvestments\t2343\t2771\t2418\nDivestments\t499\t133\t216\nROACE\t8%\t7%\t20%\n", "q10k_tbl_66": "(M€)\t2010\t2009\t2008\nNon-Group sales\t17490\t14726\t20150\nOperating income(a)\t964\t553\t(58)\nEquity in income (loss) of affiliates and other items\t215\t(58)\t(34)\nTax on net operating income\t(267)\t(92)\t76\nNet operating income(a)\t912\t403\t(16)\nAdjustments affecting net operating income\t(55)\t(131)\t684\nAdjusted net operating income(b)\t857\t272\t668\nInvestments\t641\t631\t1074\nDivestments\t347\t47\t53\nROACE\t12%\t4%\t9%\n", "q10k_tbl_67": "(M€)\t2010\t2009\t2008\nCash flow from operating activities\t18493\t12360\t18669\nIncluding (increase) decrease in working capital\t(496)\t(3316)\t2571\nCash flow used in investing activities\t(11957)\t(10268)\t(11055)\nTotal expenditures\t(16273)\t(13349)\t(13640)\nTotal divestments\t4316\t3081\t2585\nCash flow used in financing activities\t(3348)\t(2868)\t(793)\nNet increase (decrease) in cash and cash equivalents\t3188\t(776)\t6821\nEffect of exchange rates\t(361)\t117\t(488)\nCash and cash equivalents at the beginning of the period\t11662\t12321\t5988\nCash and cash equivalents at the end of the period\t14489\t11662\t12321\n", "q10k_tbl_68": "\tLess\t\t\tMore\t\n\tthan\t1-3\t3-5\tthan\t\nPayment due by period (M€)\t1 year\tyears\tyears\t5 years\tTotal\nNon-current debt obligations(a)\t0\t6831\t5561\t6346\t18738\nCurrent portion of non-current debt obligations(b)\t3483\t0\t0\t0\t3483\nFinance lease obligations(c)\t23\t68\t61\t46\t198\nAsset retirement obligations(d)\t177\t486\t386\t4868\t5917\nOperating lease obligations(c)\t582\t757\t504\t1105\t2948\nPurchase obligations(e)\t6347\t7511\t6916\t40519\t61293\nTotal\t10612\t15653\t13428\t52884\t92577\n", "q10k_tbl_69": "(a)\tNon-current debt obligations are included in the items \"Non-current financial debt\" and \"Hedging instruments of non-current financial debt\" of the Consolidated Balance Sheet. The figure in this table is net of the non-current portion of issue swaps and swaps hedging bonds and excludes non-current finance lease obligations of €175 million.\n(b)\tThe current portion of non-current debt is included in the items \"Current borrowings\" \"Current financial assets\" and \"Other current financial liabilities\" of the balance sheet. The figure in this table is net of the current portion of issue swaps and swaps hedging bonds and excludes the current portion of finance lease obligations of €23 million.\n(c)\tFinance lease obligations and operating lease obligations: the Group leases real estate retail stations ships and other equipment through non-cancelable capital and operating leases. These amounts represent the future minimum lease payments on non-cancelable leases to which the Group is committed as of December 31 2010 less the financial expense due on finance lease obligations for €43 million.\n(d)\tThe discounted present value of Upstream asset retirement obligations primarily asset removal costs at the completion date.\n(e)\tPurchase obligations are obligations under contractual agreements to purchase goods or services including capital projects. These obligations are enforceable and legally binding on TOTAL and specify all significant terms including the amount and the timing of the payments. These obligations mainly include: hydrocarbon unconditional purchase contracts (except where an active highly liquid market exists and when the hydrocarbons are expected to be re-sold shortly after purchase) reservation of transport capacities in pipelines unconditional exploration works and development works in Upstream and contracts for capital investment projects in Downstream. This disclosure does not include contractual exploration obligations with host states where a monetary value is not attributed and purchases of booking capacities in pipelines where the Group has a participation superior to the capacity used.\n", "q10k_tbl_70": "0\tChristophe de Margerie Chairman of the Executive Committee (Chairman and Chief Executive Officer);\n0\tFrançois Cornélis Vice Chairman of the Executive Committee (President of the Chemicals segment);\n0\tMichel Bénézit (President of the Refining & Marketing division);\n0\tYves-Louis Darricarrère (President of the Exploration & Production division);\n0\tJean-Jacques Guilbaud (Chief Administrative Officer); and\n0\tPatrick de La Chevardière (Chief Financial Officer).\n", "q10k_tbl_71": "0\ta fixed amount of €20000 was paid to each director (paid prorata temporis in case of a change during the period) apart from the Chairman of the Audit Committee who was paid €30000 and the other Audit Committee members who were paid €25000;\n0\tan amount of €5000 per director for each Board of Directors' meeting effectively attended;\n0\tan amount of €3500 per director for each Compensation Committee or Nominating & Governance Committee's meetings effectively attended;\n0\tan amount of €7000 per director for each Audit Committee's meeting effectively attended;\n0\ta premium of €2000 in case the attendance to a Board of Directors or Committee meeting involves a trip from a country other than France;\n0\tthe Chairman and Chief Executive Officer does not receive directors' fees as director of TOTAL S.A. or any other company of the Group; and\n0\tuntil his duties of Chairman of the Board of TOTAL S.A. expired Mr. Desmarest did not receive any directors' fees as director of TOTAL S.A.\n", "q10k_tbl_72": "0\tMr. Desmarest received due to his previous employment by the Group a supplementary pension amounting to €320341 for 2010 (retired since May 22 2010). The value of the annual supplementary pension for a complete year would amount to nearly €549155 (December 31 2010 value) adjusted in line with changes in the value of the ARRCO pension point.\n0\tFor Mr. Tchuruk the annual supplementary pension related to his previous employment by the Group was approximately €74914 (December 31 2010 value) adjusted in line with changes in the value of the ARRCO pension point.\n", "q10k_tbl_73": "\t\t\t\t\tBenefits or advantages\n\t\tBenefits or Advantages\t\t\tdue or likely to be\n\t\tdue or likely to be due\t\tBenefits related\tdue after\nSummary table\tEmployment\tupon termination or\t\tto a non-compete\ttermination or\nas of February 28 2011\tcontract\tchange of office\t\tagreement\tchange of office\nThierry Desmarest Chairman of the Board of Directors until May 21 2010(a) Member of the Board since May 1995(a) Term of office: May 21 2010\tNO\tNO\t\tNO\tYES (retirement benefit)(c) (defined supplementary pension plan and corporate RECOSUP defined contribution pension plan(d) also applicable to certain Group employees)\nChristophe de Margerie\tNO\tYES\t\tNO\tYES\nChairman and Chief Executive Officer Member of the Board since February 2007(b) Term of current office: The Shareholders' Meeting called in 2012 to approve the financial statements for the year ending December 31 2011\t\t(termination benefit\t)(e)\t\t(retirement benefit)(e) (defined supplementary pension plan(f) and corporate RECOSUP defined contribution pension plan(g) also applicable to certain Group employees)\n", "q10k_tbl_74": "(a)\tChairman and Chief Executive Officer until February 13 2007 and Chairman of the Board of Directors from February 14 2007 to May 21 2010.\n(b)\tChief Executive Officer since February 13 2007 and Chairman and Chief Executive Officer since May 21 2010.\n(c)\tPayment subject to a performance condition in accordance with the decision of the Board of Directors on February 11 2009.\n(d)\tMr. Desmarest's pension benefit represented a booked expense of €813.57 for the period between January 1 and May 21 2010.\n(e)\tPayment subject to a performance condition in accordance with the decision of the Board of Directors on February 11 2009 and confirmed by the Board of Directors on May 15 2009 and May 21 2010. The retirement benefit cannot be combined with the compensation for loss of office described above.\n(f)\tRepresenting an annual pension that would be equivalent as of December 31 2010 to 19.47% of the annual compensation for 2010.\n(g)\tMr. de Margerie's pension benefit represented a booked expense of €2077.20 for fiscal year 2010.\n", "q10k_tbl_75": "0\tis equal to zero if the ROE is less than or equal to 10%;\n0\tvaries on a straight-line basis between 0% and 80% if the ROE is more than 10% and less than 18%;\n0\tvaries on a straight-line basis between 80% and 100% if the ROE is more than or equal to 18% and less than 30%; and\n0\tis equal to 100% if the ROE is more than or equal to 30%.\n", "q10k_tbl_76": "0\tFor 50% of the share subscription options granted the performance condition states that the number of options finally granted is based on the average ROE of the Group. The average ROE is calculated by the Group based on TOTAL's consolidated balance sheet and statement of income for fiscal years 2010 and 2011. The acquisition rate is equal to zero if the average ROE is less than or equal to 7% varies on a straight-line basis between 0% and 100% if the average ROE is more than 7% and less than 18% and is equal to 100% if the average ROE is more than or equal to 18%.\n0\tFor 50% of the share subscription options granted the performance condition states that the number of options finally granted is based on the average ROACE of the Group calculated based on TOTAL's consolidated balance sheet and statement of income for fiscal years 2010 and 2011. The acquisition rate is equal to zero if the average ROACE is less than or equal to 6% varies on a straight-line basis between 0% and 100% if the average ROACE is more than 6% and less than 15%; and is equal to 100% if the average ROACE is more than or equal to 15%.\n", "q10k_tbl_77": "0\tthe first 3000 options two-thirds of the options above the first 3000 options and below the first 50000 options and one-third of the options in excess of the first 50000 options will be finally granted to their beneficiary;\n0\tthe remaining options that is one-third of the options above the first 3000 options and below the first 50000 options and two-thirds of the options in excess of the first 50000 options will be finally granted provided that the performance condition is fulfilled.\n", "q10k_tbl_78": "0\tFor 50% of the share subscription options granted the performance condition states that the number of options finally granted is based on the average ROE of the Group as published by TOTAL. The average ROE is calculated based on the Group's consolidated balance sheet and statement of income for fiscal years 2009 and 2010. The acquisition rate is equal to zero if the average ROE is less than or equal to 7% varies on a straight-line basis between 0% and 100% if the average ROE is more than 7% and less than 18% and is equal to 100% if the average ROE is more than or equal to 18%.\n0\tFor 50% of the share subscription options granted the performance condition states that the number of options granted is related to the average ROACE of the Group as published by TOTAL. The average ROACE is calculated based on the Group's consolidated balance sheet and statement of income for fiscal years 2009 and 2010. The acquisition rate is equal to zero if the average ROACE is less than or equal to 6% varies on a straight-line basis between 0% and 100% if the average ROACE is more than 6% and less than 15%; and is equal to 100% if the average ROACE is more than or equal to 15%.\n", "q10k_tbl_79": "0\tis equal to zero if the ROE is less than or equal to 10%;\n0\tvaries on a straight-line basis between 0% and 80% if the ROE is more than 10% and less than 18%;\n0\tvaries on a straight-line basis between 80% and 100% if the ROE is more than or equal to 18% and less than 30%; and\n0\tis equal to 100% if the ROE is more than or equal to 30%.\n", "q10k_tbl_80": "For the year ended (€)\t2010\t2009\nThierry Desmarest\t\t\nChairman of the Board of Directors\t\t\n(until May 21 2010)\t\t\nCompensation due for fiscal year(a)\t1604039\t1971852\nValue of options awarded\t0\t0\nValue of restricted shares awarded\t0\t0\nTotal\t1604039\t1971852\nChristophe de Margerie Chief Executive Officer\t\t\n(until May 21 2010)\t\t\nChairman and Chief Executive Officer\t\t\n(since May 21 2010)\t\t\nCompensation due for fiscal year as Chief Executive Officer(a)\t1030359\t2666991\nCompensation due for fiscal year as Chairman and Chief Executive Officer(a)\t1977763\t0\nIn-kind benefits(b)\t6908\t6780\nValue of options awarded(c)\t1387200\t1676000\nValue of restricted shares awarded\t0\t0\nTotal\t4402230\t4349771\n", "q10k_tbl_81": "\tFor the year ended 2010\t\t\t\tFor the year ended 2009\t\n\tAmount\t\tAmount\t\tAmount\tAmount\n\tdue for\t\tpaid in\t\tdue for\tpaid in\n\t2010\t\t2010(a)\t\t2009\t2009(a)\nThierry Desmarest\t\t\t\t\t\t\nChairman of the Board of Directors\t\t\t\t\t\t\n(until May 21 2010)\t\t\t\t\t\t\nFixed compensation\t428763\t\t428763\t\t1100000\t1100000\nVariable compensation(b)\t322644\t\t871852\t\t871852\t969430\nExtraordinary compensation(c)\t492963\t\t492963\t\t0\t0\nPension benefits(d)\t320341\t\t320341\t\t0\t0\nDirectors' fees(e)\t39328\t\t39328\t\t0\t0\nIn-kind benefits\t0\t\t0\t\t0\t0\nTotal\t1604039\t\t2153247\t\t1971852\t2069430\n\tFor the year ended 2010\t\t\t\tFor the year ended 2009\t\n\tAmount\t\tAmount\t\tAmount\tAmount\n\tdue for\t\tpaid in\t\tdue for\tpaid in\n\t2010\t\t2010(a)\t\t2009\t2009(a)\nChristophe de Margerie\t\t\t\t\t\t\nChief Executive Officer\t\t\t\t\t\t\n(until May 21 2010)\t\t\t\t\t\t\nChairman and Chief Executive Officer\t\t\t\t\t\t\n(since May 21 2010)\t\t\t\t\t\t\nFixed compensation\t1426452\t(f)\t1426452\t(f)\t1310000\t1310000\nVariable compensation(g)\t1581670\t(h)\t1356991\t\t1356991\t1552875\nExtraordinary compensation\t0\t\t0\t\t0\t0\nDirectors' fees\t0\t\t0\t\t0\t0\nIn-kind benefits(i)\t6908\t\t6908\t\t6780\t6780\nTotal\t3015030\t\t2790351\t\t2673771\t2869655\n", "q10k_tbl_82": "(a)\tVariable portion paid for prior fiscal year.\n(b)\tThe variable portion for the Chairman of the Board is calculated by taking into account the Group's return on equity during the relevant fiscal year the Group's earnings compared to those of the other major international oil companies that are its competitors as well as the Chairman of the Board's personal contribution to the Group strategy corporate governance and performance. The variable portion can reach a maximum amount of 100% of the fixed base salary. The objectives related to personal contribution were considered to be substantially fulfilled in 2010.\n(c)\tRetirement benefit received.\n(d)\tRetirement benefit received in 2010 under the RECOSUP pension scheme and the defined supplementary pension plan.\n(e)\tDirectors' fees received for the directorship after May 21 2010; Mr. Desmarest did not receive any directors' fees when serving in the position of Chairman of the Board.\n(f)\tIncludes a fixed portion of €507097 for the period between January 1 and May 21 2010 and €919355 for the period between May 22 and December 31 2010.\n(g)\tThe variable portion for the Chairman and Chief Executive Officer is calculated by taking into account the Group's return on equity during the relevant fiscal year the Group's earnings compared to those of the other major international oil companies that are its competitors as well as the Chairman and Chief Executive Officer's personal contribution based on operational target criteria. The variable portion can reach a maximum amount of 165% of the fixed base salary. The objectives related to personal contribution were considered to be mostly met in 2010.\n(h)\tIncluding a variable portion of €523262 for the period between January 1 to May 21 2010 and €1058408 for the period between May 22 and December 31 2010.\n(i)\tMr. de Margerie has the use of a company car.\n", "q10k_tbl_83": "Gross amount (€)\t2010\t\t2009\t\nChristophe de Margerie\t\t(a)\t\t(a)\nThierry Desmarest(b)\t\t(a)\t\t(a)\nPatrick Artus(b)\t55000\t\t27656\t\nPatricia Barbizet(c)\t107000\t\t94192\t\nDaniel Bouton\t55000\t\t60000\t\nGunnar Brock(d)\t39328\t\t0\t\nClaude Clément(d)\t127929\t(e)\t0\t\nBertrand Collomb\t71000\t\t75000\t\nPaul Desmarais Jr.\t45000\t\t48000\t\nBertrand Jacquillat\t95000\t\t95000\t\nAnne Lauvergeon\t45000\t\t45000\t\nPeter Levene of Portsoken\t79000\t\t69000\t\nClaude Mandil\t55000\t\t55000\t\nMichel Pébereau\t71000\t\t70000\t\nThierry de Rudder\t142000\t\t116000\t\nSerge Tchuruk(f)\t104639\t(g)\t154379\t(g)\n", "q10k_tbl_84": "(a)\tFor Mr. Desmarest and the Chairman and Chief Executive Officer see summary tables \"- Summary of compensation stock options and restricted shares awarded to the Chairman and the Chief Executive Officer\" and \"- Compensation of the Chairman and the Chief Executive Officer\".\n(b)\tMember of the Compensation Committee since May 21 2010.\n(c)\tChairperson of the Audit Committee since July 28 2009.\n(d)\tDirector since May 21 2010.\n(e)\tIncluding the directors fees received representing €32328 as well as the compensation received from Total Raffinage Marketing (a subsidiary of TOTAL S.A.) representing €95601 in 2010.\n(f)\tDirector until May 21 2010.\n(g)\tIncluding pension payments related to previous employment by the Group which amounted to €74379 in 2009 and €74914 in 2010.\n", "q10k_tbl_85": "\t\t\t\tNumber of options\t\t\t\n\t\t\tValue of\tawarded during\tExercise\tExercise\tPerformance\n\tDate of plan\tType of options\toptions (€)(a)\tfiscal year (b)\tprice (€)\tperiod\tconditions\nThierry Desmarest\t2010 Plan\tSubscription\t0\t0\t0\t0\t0\nChairman of the Board of Directors\t09/14/2010\toptions\t\t\t\t\t\n(until May 21 2010)\t\t\t\t\t\t\t\nTotal\t\t\t0\t0\t\t\t\nChristophe de Margerie\t2010 Plan 09/14/2010\tSubscription options\t1387200\t240000\t38.20\t09/15/2012 09/14/2018\t\nChief Executive Officer (until May 21 2010) Chairman and Chief Executive Officer (since May 21 2010)\t\t\t\t\t\t\tFor 50% of the options the condition is based on the average ROE for the Group's 2010 and 2011 fiscal years.\n\t\t\t\t\t\t\tFor 50% of the options the condition is based on the average ROACE for the Group's 2010 and 2011 fiscal years.\nTotal\t\t\t1387200\t240000\t\t\t\n", "q10k_tbl_86": "\t\tNumber of options\t\n\tDate of plan\texercised during\tExercise\n\t(Grant date)\tfiscal year\tprice (€)\nThierry Desmarest\t2002 Plan\t25372\t39.03\nChairman of the Board of Directors\t07/09/2002\t\t\n(until May 21 2010)\t\t\t\nTotal\t\t25372\t\nChristophe de Margerie\t0\t0\t0\nChief Executive Officer\t\t\t\n(until May 21 2010)\t\t\t\nChairman and Chief Executive Officer\t\t\t\n(since May 21 2010)\t\t\t\nTotal\t\t0\t\n", "q10k_tbl_87": "\t\tNumber of shares\t\t\t\t\n\t\tawarded during\tValue of\tAcquisition\tAvailability\tPerformance\n\tDate of plan\tfiscal year\tshares (€)\tdate\tdate\tcondition\nThierry Desmarest\t2010 Plan\t0\t0\t0\t0\t0\nChairman of the Board of Directors\t09/14/2010\t\t\t\t\t\n(until May 21 2010)\t\t\t\t\t\t\nChristophe de Margerie\t2010 Plan\t0\t0\t0\t0\t0\nChief Executive Officer\t09/14/2010\t\t\t\t\t\n(until May 21 2010)\t\t\t\t\t\t\nChairman and Chief Executive Officer\t\t\t\t\t\t\n(since May 21 2010)\t\t\t\t\t\t\nClaude Clément\t2010 Plan\t240\t35.03\t09/15/2012\t09/15/2014\t\nDirector representing employee shareholders\t09/14/2010\t\t\t\t\tCondition based on the Group's average ROE for fiscal years 2010 and 2011(a)\n\t2010 Global Plan\t25\t32.70\t07/01/2012\t07/01/2014\t0\n\t06/30/2010\t\t\t\t\t\nTotal\t\t265\t\t\t\t\n", "q10k_tbl_88": "\t\tNumber of shares\t\n\t\tfinally awarded during\tAcquisition\n\tDate of plan\tfiscal year(a)\tcondition\nThierry Desmarest\t2008 Plan\t0\t0\nChairman of the Board of Directors\t10/09/2008\t\t\n(until May 21 2010)\t\t\t\nChristophe de Margerie\t2008 Plan\t0\t0\nChief Executive Officer\t10/09/2008\t\t\n(until May 21 2010)\t\t\t\nChairman and Chief Executive Officer\t\t\t\n(since May 21 2010)\t\t\t\nClaude Clément Director representing employee shareholders\t2008 Plan 10/09/2008\t300\tCondition based on the Group's ROE for fiscal year 2009\nTotal\t\t300\t\n", "q10k_tbl_89": "(a)\tShares finally awarded to the beneficiaries after a 2-year vesting period i.e. on October 10 2010.\n(b)\tThe acquisition rate of the shares granted linked to the performance condition was 60%. By decision of the Board of Directors at its meeting on September 9 2008 Mr. Clément was awarded 500 restricted shares on October 9 2008. Moreover the transfer of the restricted shares finally awarded will only be permitted after the end of a 2-year mandatory holding period i.e. from October 10 2012.\n", "q10k_tbl_90": "\t\t\tNumber of\t\tAverage number\n\t\tNumber of\toptions\t\tof options per\n\t\tbeneficiaries\tawarded(a)\tPercentage\tbeneficiary(a)\n2002 Plan(b)(d)(e):\t\t\t\t\t\nPurchase options\tExecutive officers(c)\t28\t333600\t11.6%\t11914\nDecision of the Board on July 9 2002\tSenior managers\t299\t732500\t25.5%\t2450\nExercise price: €158.30; discount: 0.0%\tOther employees\t3537\t1804750\t62.9%\t510\nExercise price as of May 24 2006: €39.03(a)\t\t\t\t\t\n\tTotal\t3864\t2870850\t100%\t743\n2003 Plan(b)(d):\t\t\t\t\t\nSubscription options\tExecutive officers(c)\t28\t356500\t12.2%\t12732\nDecision of the Board on July 16 2003\tSenior managers\t319\t749206\t25.5%\t2349\nExercise price: €133.20; discount: 0.0%\tOther employees\t3603\t1829600\t62.3%\t508\nExercise price as of May 24 2006: €32.84(a)\t\t\t\t\t\n\tTotal\t3950\t2935306\t100%\t743\n2004 Plan(d):\t\t\t\t\t\nSubscription options\tExecutive officers(c)\t30\t423500\t12.6%\t14117\nDecision of the Board on July 20 2004\tSenior managers\t319\t902400\t26.8%\t2829\nExercise price: €159.40; discount: 0.0%\tOther employees\t3997\t2039730\t60.6%\t510\nExercise price as of May 24 2006: €39.30(a)\t\t\t\t\t\n\tTotal\t4346\t3365630\t100%\t774\n2005 Plan(d):\t\t\t\t\t\nSubscription options\tExecutive officers(c)\t30\t370040\t24.3%\t12335\nDecision of the Board on July 19 2005\tSenior managers\t330\t574140\t37.6%\t1740\nExercise price: €198.90; discount: 0.0%\tOther employees\t2361\t581940\t38.1%\t246\nExercise price as of May 24 2006: €49.04(a)\t\t\t\t\t\n\tTotal\t2721\t1526120\t100%\t561\n2006 Plan(d):\t\t\t\t\t\nSubscription options\tExecutive officers(c)\t28\t1447000\t25.3%\t51679\nDecision of the Board on July 18 2006\tSenior managers\t304\t2120640\t37.0%\t6976\nExercise price: €50.60; discount: 0.0%\tOther employees\t2253\t2159600\t37.7%\t959\n\tTotal\t2585\t5727240\t100%\t2216\n2007 Plan(d)(e):\t\t\t\t\t\nSubscription options\tExecutive officers(c)\t27\t1329360\t22.8%\t49236\nDecision of the Board on July 17 2007\tSenior managers\t298\t2162270\t37.1%\t7256\nExercise price: €60.10; discount: 0.0%\tOther employees\t2401\t2335600\t40.1%\t973\n\tTotal\t2726\t5827230\t100%\t2138\n2008 Plan(d)(e)(f):\t\t\t\t\t\nSubscription options\tExecutive officers(c)\t26\t1227500\t27.6%\t47212\nAwarded on October 9 2008(g)\tSenior managers\t298\t1988420\t44.7%\t6673\nExercise price: €42.90; discount: 0.0%\tOther employees\t1690\t1233890\t27.7%\t730\n\tTotal\t2014\t4449810\t100%\t2209\n2009 Plan(d)(e):\t\t\t\t\t\nSubscription options\tExecutive officers(c)\t26\t1201500\t27.4%\t46211\nDecision of the Board on September 15 2009\tSenior managers\t284\t1825540\t41.6%\t6428\nExercise price: €39.90; discount: 0.0%\tOther employees\t1742\t1360460\t31.0%\t781\n\tTotal\t2052\t4387500\t100%\t2138\n2010 Plan(d)(e):\t\t\t\t\t\nSubscription options\tExecutive officers(c)\t25\t1348100\t28.2%\t53924\nDecision of the Board on September 14 2010\tSenior managers\t282\t2047600\t42.8%\t7261\nExercise price: €38.20; discount: 0.0%\tOther employees\t1790\t1392720\t29.0%\t778\n\tTotal\t2097\t4788420\t100%\t2283\n", "q10k_tbl_91": "(a)\tTo take into account the spin-off of Arkema pursuant to Articles 174-9 174-12 and 174-13 of Decree No. 67-236 of March 23 1967 effective at that time and as of the date of the Shareholders' Meeting on May 12 2006 at its meeting of March 14 2006 the Board of Directors resolved to adjust the rights of holders of TOTAL stock options. For each plan and each holder the exercise prices for TOTAL stock options were multiplied by 0.986147 and the number of unexercised stock options was multiplied by 1.014048 (and then rounded up) effective as of May 24 2006. In addition to take into account the four-for-one stock split approved by the Shareholders' Meeting on May 12 2006 the exercise price for stock options was divided by four and the number of unexercised stock options was multiplied by four. The presentation in this table of the number of options initially awarded has not been adjusted to reflect the four-for-one stock split.\n(b)\tCertain employees of the Elf Aquitaine group in 1998 also benefited in 2000 2001 2002 and 2003 from the vesting of Elf Aquitaine options awarded in 1998 subject to performance conditions related to the Elf Aquitaine group from 1998 to 2002. These Elf Aquitaine plans expired on March 31 2005.\n(c)\tMembers of the Management Committee and the Treasurer as of the date of the Board meeting awarding the options. Mr. Desmarest has no longer been a member of the Management Committee since February 14 2007. Mr. Desmarest was awarded 110000 options under the 2007 plan and no option under the 2008 and 2009 plans.\n(d)\tThe options are exercisable subject to a continued employment condition after a 2-year vesting period from the date of the Board meeting awarding the options and expire eight years after this date. The underlying shares may not be transferred during the 4-year period from the date of the Board meeting awarding the options (except for the 2008 plan). The continued employment condition states that the termination of the employment contract will also terminate the grantee's right to exercise the options.\n(e)\tThe 4-year transfer restriction period does not apply to employees of non-French subsidiaries as of the date of the grant who may transfer the underlying shares after a 2-year period from the date of the grant.\n(f)\tFor the 2008 plan the options acquisition rate linked to the performance condition was 60%.\n(g)\tDecision of the Board on September 9 2008.\n", "q10k_tbl_92": "\t2002 Plan\t2003 Plan\t2004 Plan\t2005 Plan\t2006 Plan\t2007 Plan\t2008 Plan\t2009 Plan\t2010 Plan\t\n\tPurchase\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\t\nType of options\toptions\toptions\toptions\toptions\toptions\toptions\toptions\toptions\toptions\tTotal\nDate of the Shareholders' Meeting\t05/17/2001\t05/17/2001\t05/14/2004\t05/14/2004\t05/14/2004\t05/11/2007\t05/11/2007\t05/11/2007\t05/21/2010\t\nGrant date(a)\t07/09/2002\t07/16/2003\t07/20/2004\t07/19/2005\t07/18/2006\t07/17/2007\t10/09/2008\t09/15/2009\t09/14/2010\t\nTotal number of options awarded including(b):\t11483400\t11741224\t13462520\t6104480\t5727240\t5937230\t4449810\t4387500\t4788420\t68081824\ndirectors(c)\t240000\t240000\t240000\t240720\t400720\t310840\t200660\t200000\t240000\t2312940\n- D. Boeuf\tn/a\tn/a\t0\t720\t720\t840\t660\t0\tn/a\t2940\n- T. Desmarest\t240000\t240000\t240000\t240000\t240000\t110000\t0\t0\t0\t1310000\n- C. de Margerie\tn/a\tn/a\tn/a\tn/a\t160000\t200000\t200000\t200000\t240000\t1000000\n- C. Clément\tn/a\tn/a\tn/a\tn/a\tn/a\tn/a\tn/a\tn/a\t0\t0\nAdditional grant\t0\t0\t24000\t134400\t0\t0\t0\t0\t0\t158400\nAdjustments related to the spin-off of Arkema(d)\t165672\t163180\t196448\t90280\t0\t0\t0\t0\t0\t615580\nDate as of which the options may be exercised\t07/10/2004\t07/17/2005\t07/21/2006\t07/20/2007\t07/19/2008\t07/18/2009\t10/10/2010\t09/16/2011\t09/15/2012\t\nExpiry date\t07/09/2010\t07/16/2011\t07/20/2012\t07/19/2013\t07/18/2014\t07/17/2015\t10/09/2016\t09/15/2017\t09/14/2018\t\nExercise price (€)(e)\t39.03\t32.84\t39.30\t49.04\t50.60\t60.10\t42.90\t39.90\t38.20\t\nCumulative number of options exercised as of December 31 2010\t6878373\t6072598\t1050178\t38497\t8620\t0\t0\t1080\t0\t\nCumulative number of options canceled as of December 31 2010\t4770699\t97362\t293943\t111807\t77734\t70785\t100652\t14650\t1120\t\nNumber of options:\t\t\t\t\t\t\t\t\t\t\n- outstanding as of January 1 2010\t5935261\t6811629\t12495709\t6185440\t5645686\t5871665\t4441630\t4377010\t0\t51764030\nAwarded in 2010\t0\t0\t0\t0\t0\t0\t0\t0\t4788420\t4788420\n- Canceled in 2010(f)(g)\t(4671989)\t(1420)\t(15660)\t(6584)\t(4800)\t(5220)\t(92472)\t(4040)\t(1120)\t(4803305)\n- exercised in 2010\t(1263272)\t(1075765)\t(141202)\t0\t0\t0\t0\t(1080)\t0\t(2481319)\noutstanding as of December 31 2010\t0\t5734444\t12338847\t6178856\t5640886\t5866445\t4349158\t4371890\t4787300\t49267826\n", "q10k_tbl_93": "(a)\tThe grant date is the date of the Board meeting awarding the options except for the share subscription option plan of October 9 2008 approved by the Board on September 9 2008.\n(b)\tThe number of options awarded before May 23 2006 has been multiplied by four to take into account the four-for-one stock split approved by the Shareholders' Meeting on May 12 2006.\n(c)\tOptions awarded to directors at the time of grant.\n(d)\tAdjustments approved by the Board on its meeting on March 14 2006 pursuant to Articles 174-9 174-12 and 174-13 of Decree No. 67-236 dated March 23 1967 in effect at the time of the Board meeting as well as at the time of the Shareholders' Meeting on May 12 2006 related to the spin-off of Arkema. These adjustments were made on May 22 2006 effective as of May 24 2006.\n(e)\tExercise price as of May 24 2006. To take into account the four-for-one stock split that took place on May 18 2006 the exercise price of stock options from plans then effective has been divided by four. In addition to take into account the spin-off of Arkema the exercise price of stock options was multiplied by an adjustment ratio of 0.986147 effective as of May 24 2006. Exercise prices prior to May 24 2006 are shown in Note 25 to the Consolidated Financial Statements.\n(f)\tOut of the 4671989 options canceled in 2010 4671145 options that were not exercised expired due to the expiry of the 2002 purchase option plan on July 9 2010.\n(g)\tOut of the 92472 options awarded under the 2008 plan that were canceled 88532 options were canceled due to the application of the performance condition. The acquisition rate applicable to the subscription options that were subject to the performance condition of the 2008 plan was 60%.\n", "q10k_tbl_94": "\t2002 Plan\t2003 Plan\t2004 Plan\t2005 Plan\t2006 Plan\t2007 Plan\t2008 Plan\t2009 Plan\t2010 Plan\t\n\tPurchase\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\t\nType of options\toptions\toptions\toptions\toptions\toptions\toptions\toptions\toptions\toptions\tTotal\nExpiry date\t07/09/2010\t07/16/2011\t07/20/2012\t07/19/2013\t07/18/2014\t07/17/2015\t10/09/2016\t09/15/2017\t09/14/2018\t\nExercise price (€)(a)\t39.03\t32.84\t39.30\t49.04\t50.60\t60.10\t42.90\t39.90\t38.20\t\nOptions awarded by the Board(b)\t560200\t635704\t796800\t689680\t823720\t1000840\t1101200\t1169800\t1348100\t8126044\nAdjustments related to the spin-off of Arkema(c)\t7568\t8120\t11248\t9608\t0\t0\t0\t0\t0\t36544\nOptions outstanding as of 01/01/10\t243232\t291337\t705048\t699416\t823720\t1000840\t1101200\t1169800\t0\t6034593\nOptions awarded in 2010\t0\t0\t0\t0\t0\t0\t0\t0\t1348100\t1348100\nOptions exercised in 2010\t(20600)\t(25172)\t(90000)\t0\t0\t0\t0\t0\t0\t(135772)\nOptions canceled in 2010(d)(e)\t(222632)\t0\t0\t0\t0\t0\t(78399)\t0\t0\t(301031)\nOptions outstanding as of 12/31/10\t0\t266165\t615048\t699416\t823720\t1000840\t1022801\t1169800\t1348100\t6945890\n", "q10k_tbl_95": "(a)\tExercise price as of May 24 2006. To take into account the four-for-one stock split that took place on May 18 2006 the exercise price of stock options from plans then effective has been divided by four. In addition to take into account the spin-off of Arkema the exercise price of stock options was multiplied by an adjustment ratio of 0.986147 effective as of May 24 2006. Exercise prices prior to May 24 2006 are shown in Note 25 to the Consolidated Financial Statements.\n(b)\tThe number of options awarded before May 23 2006 has been multiplied by four to take into account the four-for-one stock split approved by the Shareholders' Meeting on May 12 2006.\n(c)\tAdjustments approved by the Board on its meeting on March 14 2006 pursuant to Articles 174-9 174-12 and 174-13 of Decree No. 67-236 dated March 23 1967 in effect at the time of the Board meeting and at the time of the Shareholders' Meeting on May 12 2006 related to the spin-off of Arkema. These adjustments were made on May 22 2006 effective as of May 24 2006.\n(d)\tOut of the 301031 options canceled in 2010 222632 options that were not exercised expired due to the expiry of the 2002 purchase option plan on July 9 2010.\n(e)\t78399 options of the 2008 plan were canceled due to the application of the performance condition. The acquisition rate applicable to the subscription options that were subject to the performance condition of the 2008 plan was 60%.\n", "q10k_tbl_96": "\t2002 Plan\t2003 Plan\t2004 Plan\t2005 Plan\t2006 Plan\t2007 Plan\t2008 Plan\t2009 Plan\t2010 Plan\t\n\tPurchase\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\t\nType of options\toptions\toptions\toptions\toptions\toptions\toptions\toptions\toptions\toptions\tTotal\nExpiry date\t07/09/2010\t07/16/2011\t07/20/2012\t07/19/2013\t07/18/2014\t07/17/2015\t10/09/2016\t09/15/2017\t09/14/2018\t\nExercise price (€)(a)\t39.03\t32.84\t39.30\t49.04\t50.60\t60.10\t42.90\t39.90\t38.20\t\nOptions awarded by the Board(b)\t240000\t240000\t240000\t240000\t240000\t110000\t0\t0\t0\t1310000\nAdjustments related to the spin-off of Arkema(c)\t3372\t2476\t3372\t3372\t0\t0\t0\t0\t0\t12592\nOptions outstanding as of 01/01/10\t25372\t0\t243372\t243372\t240000\t110000\t0\t0\t0\t862116\nOptions awarded in 2010\t0\t0\t0\t0\t0\t0\t0\t0\t0\t0\nOptions exercised in 2010\t(25372)\t0\t0\t0\t0\t0\t0\t0\t0\t(25372)\nOptions canceled in 2010\t0\t0\t0\t0\t0\t0\t0\t0\t0\t0\nOptions outstanding as of 12/31/10\t0\t0\t243372\t243372\t240000\t110000\t0\t0\t0\t836744\n", "q10k_tbl_97": "(a)\tExercise price as of May 24 2006. To take into account the four-for-one stock split that took place on May 18 2006 the exercise price of stock options from plans then effective has been divided by four. In addition to take into account the spin-off of Arkema the exercise price of stock options was multiplied by an adjustment ratio of 0.986147 effective as of May 24 2006. Exercise prices prior to May 24 2006 are shown in Note 25 to the Consolidated Financial Statements.\n(b)\tThe number of options awarded before May 23 2006 has been multiplied by four to take into account the four-for-one stock split approved by the Shareholders' Meeting on May 12 2006.\n(c)\tAdjustments approved by the Board on its meeting on March 14 2006 pursuant to Articles 174-9 174-12 and 174-13 of Decree No. 67-236 dated March 23 1967 in effect at the time of the Board meeting and at the time of the Shareholders' Meeting on May 12 2006 related to the spin-off of Arkema. These adjustments were made on May 22 2006 effective as of May 24 2006.\n", "q10k_tbl_98": "\t2002 Plan\t2003 Plan\t2004 Plan\t2005 Plan\t2006 Plan\t2007 Plan\t2008 Plan\t2009 Plan\t2010 Plan\t\n\tPurchase\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\tSubscription\t\nType of options\toptions\toptions\toptions\toptions\toptions\toptions\toptions\toptions\toptions\tTotal\nExpiry date\t07/09/2010\t07/16/2011\t07/20/2012\t07/19/2013\t07/18/2014\t07/17/2015\t10/09/2016\t09/15/2017\t09/14/2018\t\nExercise price (€)(a)\t39.03\t32.84\t39.30\t49.04\t50.60\t60.10\t42.90\t39.90\t38.20\t\nOptions awarded by the Board(b)\t112000\t112000\t128000\t130000\t160000\t200000\t200000\t200000\t240000\t1482000\nAdjustments related to the spin-off of Arkema(c)\t1576\t1576\t1800\t1828\t0\t0\t0\t0\t0\t6780\nOptions outstanding as of 01/01/10\t113576\t113576\t129800\t131828\t160000\t200000\t200000\t200000\t0\t1248780\nOptions awarded in 2010\t\t\t\t\t\t\t\t\t240000\t240000\nOptions exercised in 2010\t\t\t\t\t\t\t\t\t0\t0\nOptions canceled in 2010(d)(e)\t(113576)\t\t\t\t\t\t(23333)\t\t\t(136909)\nOptions outstanding as of 12/31/10\t0\t113576\t129800\t131828\t160000\t200000\t176667\t200000\t240000\t1351871\n", "q10k_tbl_99": "(a)\tExercise price as of May 24 2006. To take into account the four-for-one stock split that took place on May 18 2006 the exercise price of stock options from plans then effective has been divided by four. In addition to take into account the spin-off of Arkema the exercise price of stock options was multiplied by an adjustment ratio of 0.986147 effective as of May 24 2006. Exercise prices prior to May 24 2006 are shown in Note 25 to the Consolidated Financial Statements.\n(b)\tThe number of options awarded before May 23 2006 has been multiplied by four to take into account the four-for-one stock split approved by the Shareholders' Meeting on May 12 2006.\n(c)\tAdjustments approved by the Board on its meeting on March 14 2006 pursuant to Articles 174-9 174-12 and 174-13 of Decree No. 67-236 dated March 23 1967 in effect at the time of the Board meeting and at the time of the Shareholders' Meeting on May 12 2006 related to the spin-off of Arkema. These adjustments were made on May 22 2006 effective as of May 24 2006.\n(d)\t113576 options that were not exercised expired due to the expiry of the 2002 purchase option plan on July 9 2010.\n(e)\tThe acquisition rate applicable to the subscription options that were subject to the performance condition of the 2008 plan was 60%.\n", "q10k_tbl_100": "\tTotal number of options\t\t\t\t\n\tawarded/ options\t\t\t\t\n\texercised\tExercise price (€)\t\tGrant date(a)\tExpiry date\nOptions awarded in 2010 to the ten employees of TOTAL S.A. or any company in the Group receiving the largest number of options\t742000\t38.20\t\t09/14/2010\t09/14/2018\nOptions exercised in 2010 by the ten employees of\t75858\t39.03\t\t07/09/2002\t07/09/2010\nTOTAL S.A. or any company in the Group\t79793\t32.84\t\t07/16/2003\t07/16/2011\nexercising the largest number of options(b)\t24000\t39.30\t\t07/20/2004\t07/20/2012\n\t179651\t36.32\t(c)\t\t\n", "q10k_tbl_101": "(a)\tThe grant date is the date of the Board meeting awarding the options.\n(b)\tExercise price as of May 24 2006. To take into account the four-for-one stock split that took place on May 18 2006 the exercise price of stock options from plans then effective has been divided by four. In addition to take into account the spin-off of Arkema the exercise price of stock options was multiplied by an adjustment ratio of 0.986147 effective as of May 24 2006. Exercise prices prior to May 24 2006 are shown in Note 25 to the Consolidated Financial Statements.\n(c)\tWeighted-average price.\n", "q10k_tbl_102": "\t\t\t\t\tAverage number\n\t\t\tNumber of\t\tof restricted\n\t\tNumber of\trestricted shares\t\tshares per\n\t\tbeneficiaries\tawarded(a)\tPercentage\tbeneficiary\n2005 Plan(b)\tExecutive officers(c)\t29\t13692\t2.4%\t472\nDecision of the Board on\tSenior managers\t330\t74512\t13.1%\t226\nJuly 19 2005\tOther employees(d)\t6956\t481926\t84.5%\t69\n\tTotal\t7315\t570130\t100%\t78\n2006 Plan(b)\tExecutive officers(c)\t26\t49200\t2.2%\t1892\nDecision of the Board on\tSenior managers\t304\t273832\t12.0%\t901\nJuly 18 2006\tOther employees(d)\t7509\t1952332\t85.8%\t260\n\tTotal\t7839\t2275364\t100%\t290\n2007 Plan(b)\tExecutive officers(c)\t26\t48928\t2.1%\t1882\nDecision of the Board on\tSenior managers\t297\t272128\t11.5%\t916\nJuly 17 2007\tOther employees(d)\t8291\t2045309\t86.4%\t247\n\tTotal\t8614\t2366365\t100%\t275\n2008 Plan(b)\tExecutive officers(c)\t25\t49100\t1.8%\t1964\nGrant on October 9\tSenior managers\t300\t348156\t12.5%\t1161\n2008 by decision of\tOther employees(d)\t9028\t2394712\t85.8%\t265\nthe Board\t\t\t\t\t\non September 9 2008\tTotal\t9353\t2791968\t100%\t299\n2009 Plan\tExecutive officers(c)\t25\t48700\t1.6%\t1948\nDecision of the Board on\tSenior managers\t284\t329912\t11.1%\t1162\nSeptember 15 2009\tOther employees(d)\t9693\t2593406\t87.3%\t268\n\tTotal\t10002\t2972018\t100%\t297\n2010 Plan(e)\tExecutive officers(c)\t24\t46780\t1.6%\t1949\nDecision of the Board on\tSenior managers\t283\t343080\t11.4%\t1212\nSeptember 14 2010\tOther employees(d)\t10074\t2620151\t87.0%\t260\n\tTotal\t10381\t3010011\t100%\t290\n", "q10k_tbl_103": "(a)\tThe number of restricted shares awarded shown in this table has not been recalculated to take into account the four-for-one stock split approved by the Shareholders' Meeting on May 12 2006.\n(b)\tFor the 2005 2006 and 2007 plans the acquisition rates of the shares awarded linked to the performance conditions were 100%. For the 2008 plan the acquisition rate linked to the performance condition was 60%.\n(c)\tMembers of the Management Committee and the Treasurer as of the date of the Board meeting granting the restricted shares. The Chairman of the Board and the Chief Executive Officer were not awarded any restricted shares.\n(d)\tMr. Clément employee of Total Raffinage Marketing a subsidiary of TOTAL S.A. and the director of TOTAL S.A. representing employee shareholders was awarded 320 restricted shares under the 2005 plan 200 restricted shares under the 2007 plan 500 restricted shares under the 2008 plan and 240 restricted shares under the 2010 plan.\n(e)\tExcluding free shares granted as part of the 2010 global free share plan.\n", "q10k_tbl_104": "\t2005\t\t\t\t\t\t\t\t\n\tPlan(a)\t\t2006 Plan\t\t2007 Plan\t\t2008 Plan\t2009 Plan\t2010 Plan\nDate of the Shareholders' Meeting\t05/17/2005\t\t05/17/2005\t\t05/17/2005\t\t05/16/2008\t05/16/2008\t05/16/2008\nGrant date(b)\t07/19/2005\t\t07/18/2006\t\t07/17/2007\t\t10/09/2008\t09/15/2009\t09/14/2010\nClosing price on grant date(c)\t€52.13\t\t€50.40\t\t€61.62\t\t€35.945\t€41.615\t€39.425\nAverage repurchase price per share paid by the Company\t€51.62\t\t€51.91\t\t€61.49\t\t€41.63\t€38.54\t€39.11\nTotal number of restricted shares awarded including to\t2280520\t\t2275364\t\t2366365\t\t2791968\t2972018\t3010011\n- Directors(d)\t416\t\t416\t\t432\t\t588\t0\t240\n- Ten employees with largest grants(e)\t20000\t\t20000\t\t20000\t\t20000\t20000\t20000\nStart of the vesting period:\t07/19/2005\t\t07/18/2006\t\t07/17/2007\t\t10/09/2008\t09/15/2009\t09/14/2010\nDate of final grant subject to specific condition (end of the vesting period)\t07/20/2007\t\t07/19/2008\t\t07/18/2009\t\t10/10/2010\t09/16/2011\t09/15/2012\nTransfer possible from (end of the mandatory holding period)\t07/20/2009\t\t07/19/2010\t\t07/18/2011\t\t10/10/2012\t09/16/2013\t09/15/2014\nNumber of restricted shares:\t\t\t\t\t\t\t\t\t\n- Outstanding as of January 1 2010\t0\t\t0\t\t0\t\t2762476\t2966036\t\n- Awarded in 2010\t\t\t\t\t0\t\t\t0\t3010011\n- Canceled in 2010(f)\t1024\t(h)\t3034\t(h)\t552\t(h)\t(1113462)\t(9796)\t(8738)\n- Finally granted in 2010(g)\t(1024\t)(h)\t(3034\t)(h)\t(552\t)(h)\t(1649014)\t(1904)\t(636)\n- Outstanding as of December 31 2010\t0\t\t0\t\t0\t\t0\t2954336\t3000637\n", "q10k_tbl_105": "(a)\tThe number of restricted shares awarded has been multiplied by four to take into account the four-for-one stock split approved by TOTAL Shareholders' Meeting on May 12 2006.\n(b)\tThe grant date is the date of the Board meeting awarding the restricted share grant except for the restricted shares awarded on October 9 2008 approved by the Board on September 9 2008.\n(c)\tTo take into account the four-for-one stock split in May 18 2006 the closing price for TOTAL shares on July 19 2005 (€208.50) has been divided by four.\n(d)\tMr. Desmarest Chairman of the Board of Directors until May 21 2010 was not awarded any restricted shares under the 2005 2006 2007 2008 2009 and 2010 plans. Furthermore Mr. de Margerie director of TOTAL S.A. since May 12 2006 Chief Executive Officer of TOTAL S.A. since February 14 2007 and Chairman and Chief Executive Officer of TOTAL S.A. since May 21 2010 was not awarded any restricted shares under the 2006 2007 2008 2009 and 2010 plans. Mr. de Margerie was finally awarded on July 20 2007 the 2000 restricted shares he had been awarded under the 2005 plan since he was not a director of TOTAL S.A as of the date of the grant. In addition Mr. Boeuf director of TOTAL S.A. representing employee shareholders until December 31 2009 was awarded restricted shares under the plans approved by the Board of Directors of TOTAL S.A. on July 19 2005 July 18 2006 July 17 2007 and September 9 2008. Mr. Boeuf was not awarded any restricted shares under the plan approved by the Board of Directors of TOTAL S.A. on September 15 2009. Mr. Clément director of TOTAL S.A. representing employee shareholders since May 21 2010 was awarded 240 restricted shares under the plan approved by the Board of Directors of TOTAL S.A. on September 14 2010. In addition Mr. Clément was finally awarded 300 shares on October 10 2010 under the restricted share plan approved by the Board of Directors of TOTAL S.A. on September 9 2008.\n(e)\tEmployees of TOTAL S.A. or of any Group company who were not directors of TOTAL S.A. as of the date of grant.\n(f)\tOut of the 1113462 canceled rights to the grant share under the 2008 plan 1094914 entitlement rights were canceled due to the performance condition. The acquisition rate for the 2008 plan was 60%.\n(g)\tFor the 2009 and 2010 plans final grants following the death of the beneficiary.\n(h)\tRestricted shares finally awarded for which the entitlement right had been canceled erroneously.\n", "q10k_tbl_106": "\t2010 plan\t2010 plan\t\n\t(2+2)\t(4+0)\tTotal\nDate of the Shareholders' Meeting\t05/16/2008\t05/16/2008\t\nGrant date(a)\t06/30/2010\t06/30/2010\t\nFinal grant date (end of vesting period)\t07/01/2012\t07/01/2014\t\nTransfer possible from\t07/01/2014\t07/01/2014\t\nNumber of restricted shares awarded\t\t\t\nOutstanding as of January 1 2008\t0\t0\t0\nAwarded\t0\t0\t0\nCanceled\t0\t0\t0\nFinally granted\t0\t0\t0\nOutstanding as of January 1 2009\t0\t0\t0\nAwarded\t0\t0\t0\nCanceled\t0\t0\t0\nFinally granted\t0\t0\t0\nOutstanding as of January 1 2010\t0\t0\t0\nAwarded\t1508850\t1070650\t2579500\nCanceled\t(125)\t(75)\t(200)\nFinally granted(c)\t(75)\t\t(75)\nOutstanding as of December 31 2010\t1508650\t1070575\t2579225\n", "q10k_tbl_107": "\tRestricted share\t\t\t\t\n\tgrants / Shares\t\t\t\tEnd of mandatory\n\tfinally awarded\t\tGrant date\tDate of final grant\tholding period\nRestricted share grants approved by the Board meeting on September 14 2010 to the ten TOTAL S.A. employees (other than directors) receiving the largest amount of grants(a)\t20000\t(b)\t09/14/2010\t09/15/2012\t09/15/2014\nRestricted share finally awarded in 2010 following the restricted share plan approved by the Board meeting on September 9 2008 to the ten employees (other than directors) receiving the largest amount of shares(c)\t12000\t\t10/09/2008\t10/10/2010\t10/10/2012\n", "q10k_tbl_108": "(a)\tGrant approved by the Board on September 14 2010. Grants of these restricted shares will become final subject to a performance condition after a 2-year vesting period i.e. on September 15 2012. Moreover the transfer of the restricted shares will not be permitted until the end of a 2-year mandatory holding period i.e. on September 15 2014.\n(b)\tIn addition as of June 30 2010 as part of the global free share plan the ten employees were granted rights to twenty-five free shares.\n(c)\tRestricted share plan approved by the Board of Directors on September 9 2008 and awarded on October 9 2008. Grants of these restricted shares will become final subject to a performance condition after a 2-year vesting period i.e. on October 10 2010. The acquisition rate of the shares awarded linked to the performance condition was 60%. Moreover the transfer of the restricted shares finally awarded will only be permitted after the end of a 2-year mandatory holding period i.e. from October 10 2012.\n", "q10k_tbl_109": "0\tThe AFEP-MEDEF Code recommends that a director no longer be considered as independent upon the expiry of the term of office during which the length of his service on the board reaches twelve years. The Board has not followed this recommendation with regards to one of its members considering the long-term nature of its investments and operation as well as the experience and authority of which this director is in possession which reinforce his independence and contribute to the Board's work. This directorship expired on May 21 2010.\n0\tMr. Desmarest chairs the Nominating & Governance Committee since it was created in February 2007. Although Mr. Desmarest chaired the Board of Directors until May 2010 the Board and this Committee considered that Mr. Desmarest chairing the Nominating & Governance Committee would enable this Committee to benefit from his experience and his knowledge of the Company's businesses environment and executive teams which is particularly useful to inform the Committee's deliberations concerning the appointment of executives and directors. This committee is comprised of a majority of independent directors and the Chairman and the Chief Executive Officer do not attend deliberations concerning their own situation.\n", "q10k_tbl_110": "\tUpstream\tDownstream\tChemicals\tCorporate\tTotal\n2010\t17192\t32631\t41658\t1374\t92855\n2009\t16628\t33760\t44667\t1332\t96387\n2008\t16005\t34040\t45545\t1369\t96959\n\t\tFrance\tRest of Europe\tRest of world\tTotal\n2010\t\t35169\t24931\t32755\t92855\n2009\t\t36407\t26299\t33681\t96387\n2008\t\t37101\t27495\t32363\t96959\n", "q10k_tbl_111": "TOTAL ACTIONNARIAT FRANCE\t73117185\nTOTAL ACTIONNARIAT INTERNATIONAL CAPITALISATION\t16446122\nELF PRIVATISATION No. 1\t977948\nShares held by U.S. employees\t705829\nGroup Caisse Autonome (Belgium)\t295866\nTOTAL shares from the exercise of the Company's stock options and held as registered shares within a Company Savings Plan (PEE)(a)\t3185510\nTotal shares held by employee shareholder funds\t94728460\n", "q10k_tbl_112": "0\tMembers of the Board of Directors (including the Chairman and Chief Executive Officer): 474450 shares;\n0\tChairman and Chief Executive Officer: 85230 shares and 48529 shares of the TOTAL ACTIONNARIAT FRANCE collective investment plan;\n0\tManagement Committee (including the Chief Executive Officer) and Treasurer: 572527 shares.\n", "q10k_tbl_113": "\t\t\t\t\t\tExercise\n\t\t\t\t\t\tof stock\n\t\tAcquisition\tSubscription\tTransfer\tExchange\toptions\nThierry Desmarest(a)\tTOTAL shares\t0\t0\t45372\t0\t25372\n\tShares in collective investment plans (FCPE) and other related financial instruments(b)\t0\t0\t0\t0\t0\nChristophe de Margerie(a)\tTOTAL shares\t0\t0\t0\t0\t0\n\tShares in collective investment plans (FCPE) and other related financial instruments(b)\t4815.21\t0\t0\t0\t0\nMichel Bénézit(a)\tTOTAL shares\t0\t3170\t0\t0\t0\n\tShares in collective investment plans (FCPE) and other related financial instruments(b)\t27.68\t47.23\t0\t0\t0\nFrançois Cornélis(a)\tTOTAL shares\t0\t0\t0\t0\t0\n\tShares in collective investment plans (FCPE) and other related financial instruments(b)\t1241.32\t0\t0\t0\t0\nYves-Louis Darricarrère(a)\tTOTAL shares\t0\t0\t0\t0\t0\n\tShares in collective investment plans (FCPE) and other related financial instruments(b)\t4.61\t0\t0\t0\t0\nJean-Jacques Guilbaud(a)\tTOTAL shares\t0\t0\t5000\t0\t5000\n\tShares in collective investment plans (FCPE) and other related financial instruments(b)\t345.33\t259.48\t652.79\t0\t0\nPatrick de La Chevardière(a)\tTOTAL shares\t0\t0\t0\t0\t0\n\tShares in collective investment plans (FCPE) and other related financial instruments(b)\t79.25\t12.79\t0\t0\t0\n", "q10k_tbl_114": "\t2010\t\t\t2009\t\t2008\t\n\t\t\t% of\t\t\t\t\n\t% of\t% of\ttheoretical\t% of\t% of\t% of\t% of\n\tshare\tvoting\tvoting\tshare\tvoting\tshare\tvoting\nAs of December 31\tcapital\trights\trights(a)\tcapital\trights\tcapital\trights\nGroupe Bruxelles Lambert(b)(c)\t4.0\t4.0\t3.7\t4.0\t4.0\t4.0\t4.0\nCompagnie Nationale à Portefeuille(b)(c)\t1.6\t1.6\t1.4\t1.4\t1.4\t1.4\t1.4\nAreva(b)\t0.0\t0.0\t0.0\t0.0\t0.0\t0.3\t0.6\nBNP Paribas(b)\t0.2\t0.2\t0.2\t0.2\t0.2\t0.2\t0.2\nGroup employees(b)(d)\t4.0\t7.7\t7.1\t3.9\t7.5\t3.8\t7.4\nOther registered shareholders (non-Group)\t1.4\t2.5\t2.3\t1.4\t2.4\t1.2\t2.1\nTreasury shares\t4.8\t0\t8.3\t4.9\t0\t6.0\t0\nof which TOTAL S.A.\t0.5\t0\t0.5\t0.6\t0\t1.8\t0\nof which Total Nucléaire\t0.1\t\t0.1\t0.1\t0\t0.1\t0\nof which subsidiaries of Elf Aquitaine\t4.2\t\t7.7\t4.2\t0\t4.1\t0\nOther bearer shareholders\t84.0\t84.0\t77.0\t84.2\t84.5\t83.1\t84.3\nof which holders of ADS(e)\t8.0\t8.0\t7.4\t7.5\t7.6\t8.2\t8.3\n", "q10k_tbl_115": "(a)\tPursuant to article 223-11 of the AMF General Regulation the number of theoretical voting rights is calculated on the basis of all outstanding shares to which voting rights are attached including treasury shares that are deprived of voting rights.\n(b)\tShareholders with an executive officer (or a representative of employees) serving as a director of TOTAL S.A.\n(c)\tGroupe Bruxelles Lambert is a company controlled jointly by the Desmarais family and Frère-Bourgeois S.A. and for the latter mainly through its direct and indirect interest in Compagnie Nationale à Portefeuille. In addition Groupe Bruxelles Lambert and Compagnie Nationale à Portefeuille declared their acting in concert.\n(d)\tBased on the definition of employee shareholding pursuant to Article L. 225-102 of the French Commercial Code.\n(e)\tAmerican Depositary Shares listed on the New York Stock Exchange.\n", "q10k_tbl_116": "0\tIn the United States investigations into certain commercial practices of some subsidiaries of the Arkema group have been closed since 2007; no charges have been brought against Arkema. Civil liability lawsuits for which TOTAL S.A. has been named as the parent company are about to be closed and are not expected to have a significant impact on the Group's financial position.\n0\tIn Europe since 2006 the European Commission has fined companies of the Group in its configuration prior to the spin-off an overall amount of €385.47 million of which Elf Aquitaine and/or TOTAL S.A. and their subsidiaries were held jointly liable for €280.17 million Elf Aquitaine being personally fined €23.6 million for deterrence. These fines are entirely settled as of today.\n", "q10k_tbl_117": "Price per share (€)\tHigh\tLow\tHigh adjusted\tLow adjusted\n2006\t58.15\t46.52\t57.40\t46.52\n2007\t63.40\t48.33\t0\t0\n2008\t59.50\t31.52\t0\t0\n2009\t45.785\t34.25\t0\t0\nFirst Quarter\t42.465\t34.25\t0\t0\nSecond Quarter\t42.455\t34.72\t0\t0\nThird Quarter\t42.45\t35.75\t0\t0\nFourth Quarter\t45.785\t39.005\t0\t0\n2010\t46.735\t35.655\t0\t0\nFirst Quarter\t46.735\t40.05\t0\t0\nSecond Quarter\t44.625\t36.21\t0\t0\nThird Quarter\t41.00\t35.655\t0\t0\nSeptember\t39.67\t36.77\t0\t0\nFourth Quarter\t41.275\t36.91\t0\t0\nOctober\t39.72\t37.52\t0\t0\nNovember\t41.275\t36.91\t0\t0\nDecember\t40.79\t37.195\t0\t0\n2011 (through February 28)\t44.47\t40.01\t0\t0\nJanuary\t43.575\t40.01\t0\t0\nFebruary\t44.47\t42.325\t0\t0\n", "q10k_tbl_118": "Price Per ADR ($)\tHigh\tLow\tHigh adjusted\tLow adjusted\n2006\t73.46\t58.06\t73.46\t58.06\n2007\t87.34\t63.89\t0\t0\n2008\t91.34\t42.60\t0\t0\n2009\t65.98\t42.88\t0\t0\nFirst Quarter\t57.85\t42.88\t0\t0\nSecond Quarter\t59.93\t45.02\t0\t0\nThird Quarter\t62.43\t49.78\t0\t0\nFourth Quarter\t65.98\t57.05\t0\t0\n2010\t67.52\t43.07\t0\t0\nFirst Quarter\t67.52\t54.01\t0\t0\nSecond Quarter\t60.24\t43.07\t0\t0\nThird Quarter\t54.14\t44.43\t0\t0\nSeptember\t52.46\t48.15\t0\t0\nFourth Quarter\t58.06\t48.08\t0\t0\nOctober\t55.50\t51.20\t0\t0\nNovember\t58.06\t48.08\t0\t0\nDecember\t53.97\t49.03\t0\t0\n2011 (through February 28)\t61.44\t52.61\t0\t0\nJanuary\t59.84\t52.61\t0\t0\nFebruary\t61.44\t58.05\t0\t0\n", "q10k_tbl_119": "Fiscal 2008\t\nApril 25 2008\tCertification of the subscription to 4870386 new shares par value €2.50 as part of the capital increase reserved for Group employees approved by the Board of Directors on November 6 2007 raising the share capital by €12175965 from €5988830242.50 to €6001006207.50.\nJuly 31 2008\tReduction of the share capital from €6001006207.50 to €5926006207.50 through the cancelation of 30000000 treasury shares par value €2.50.\nJanuary 13 2009\tCertification of the issuance of 1405591 new shares par value €2.50 per share between January 1 and December 31 2008 raising the share capital by €3513977.50 from €5926006207.50 to €5929520185 (of which 1178167 new shares issued through the exercise of the Company's stock options and 227424 new shares through the exchange of 37904 shares of Elf Aquitaine stock resulting from the exercise of Elf Aquitaine stock options and eligible for a guaranteed exchange for TOTAL shares).\nFiscal 2009\t\nJuly 30 2009\tReduction of the share capital from €5929520185 to €5867520185 through the cancelation of 24800000 treasury shares par value €2.50.\nJanuary 12 2010\tCertification of the issuance of 1414810 new shares par value €2.50 per share between January 1 and December 31 2009 raising the share capital by €3537025 from €5867520185 to €5871057210 (of which 934780 new shares issued through the exercise of the Company's stock options and 480030 new shares through the exchange of 80005 shares of Elf Aquitaine stock resulting from the exercise of Elf Aquitaine stock options and eligible for a guaranteed exchange for TOTAL shares).\nFiscal 2010\t\nJanuary 12 2011\tCertification of the issuance of 1218047 new shares par value €2.50 through the exercise of the Company's stock options between January 1 and December 31 2010 raising the share capital by €3045117.50 from €5871057210 to €5874102327.50.\n", "q10k_tbl_120": "\tKPMG\t\tErnst & Young Audit\t\n\tYear Ended December 31\t\tYear Ended December 31\t\n(M€)\t2010\t2009\t2010\t2009\nAudit Fees\t15.1\t16.0\t15.2\t17.7\nAudit-Related Fees(a)\t3.6\t2.9\t0.7\t0.8\nTax Fees(b)\t1.2\t1.2\t1.7\t1.4\nAll Other Fees(c)\t0.1\t0.3\t0.2\t0.1\nTotal\t20.0\t20.4\t17.8\t20.0\n", "q10k_tbl_121": "\t\t\tTotal Number Of\t\n\t\t\tShares Purchased\tMaximum Number\n\t\t\tAs Part Of Publicly\tOf Shares That May\n\tTotal Number Of\tAverage Price\tAnnounced\tYet Be Purchased\n\tShares\tPaid Per\tPlans Or\tUnder The Plans Or\nPeriod\tPurchased\tShare (€)\tPrograms(a)\tPrograms(b)\nJanuary 2010\t0\t0\t0\t119798107\nFebruary 2010\t0\t0\t0\t119813214\nMarch 2010\t0\t0\t0\t119911829\nApril 2010\t0\t0\t0\t120319759\nMay 2010\t0\t0\t0\t120418644\nJune 2010\t0\t0\t0\t120724568\nJuly 2010\t0\t0\t0\t120734750\nAugust 2010\t0\t0\t0\t120742346\nSeptember 2010\t0\t0\t0\t120675024\nOctober 2010\t0\t0\t0\t122411798\nNovember 2010\t0\t0\t0\t122432721\nDecember 2010\t0\t0\t0\t122476414\nJanuary 2011\t0\t0\t0\t122526633\nFebruary 2011\t0\t0\t0\t122588776\n", "q10k_tbl_122": "(a)\tThe shareholders' meeting of May 21 2010 cancelled and replaced the previous resolution from the shareholders' meeting of May 15 2009 authorizing the Board of Directors to trade in the Company's own shares on the market for a period of 18 months within the framework of the stock purchase program. The maximum number of shares that may be purchased by virtue of this authorization or under the previous authorization may not exceed 10% of the total number of shares constituting the share capital this amount being periodically adjusted to take into account operations modifying the share capital after each shareholders' meeting. Under no circumstances may the total number of shares the Company holds either directly or indirectly through its subsidiaries exceed 10% of the share capital.\n(b)\tBased on 10% of the Company's share capital and after deducting the shares held by the Company for cancellation and the shares held by the Company to cover the share purchase option plans for Company employees and restricted share grants for Company employees as well as after deducting the shares held by the subsidiaries.\n", "q10k_tbl_123": "\tPage\nReport of Independent Registered Public Accounting Firms on the Consolidated Financial Statements\tF-1\nReport of Independent Registered Public Accounting Firms on the Internal Control over Financial Reporting\tF-2\nConsolidated Statement of Income for the Years Ended December 31 2010 2009 and 2008\tF-3\nConsolidated Statement of Comprehensive Income for the Years Ended December 31 2010 2009 and 2008\tF-4\nConsolidated Balance Sheet at December 31 2010 2009 and 2008\tF-5\nConsolidated Statement of Cash Flow for the Years Ended December 31 2010 2009 and 2008\tF-6\nConsolidated Statement of Changes in Shareholders' Equity for the Years Ended December 31 2010 2009 and 2008\tF-7\nNotes to the Consolidated Financial Statements\tF-8\nSupplemental Oil and Gas Information (Unaudited)\tS-1\n", "q10k_tbl_124": "1\tBylaws (Statuts) of TOTAL S.A. (as amended through December 31 2010)\n8\tList of Subsidiaries (see Note 35 to the Consolidated Financial Statements included in this Annual Report)\n11\tCode of Ethics (incorporated by reference to the Company's Annual Report on Form 20-F for the year ended December 31 2005)\n12.1\tCertification of Chairman and Chief Executive Officer\n12.2\tCertification of Chief Financial Officer\n13.1\tCertification of Chairman and Chief Executive Officer\n13.2\tCertification of Chief Financial Officer\n15\tConsent of ERNST & YOUNG AUDIT and of KPMG S.A.\n", "q10k_tbl_125": "For the year ended December 31 (M€)(a)\t\t2010\t2009\t2008\nSales\t(Notes 4 & 5)\t159269\t131327\t179976\nExcise taxes\t\t(18793)\t(19174)\t(19645)\nRevenues from sales\t\t140476\t112153\t160331\nPurchases net of inventory variation\t(Note 6)\t(93171)\t(71058)\t(111024)\nOther operating expenses\t(Note 6)\t(19135)\t(18591)\t(19101)\nExploration costs\t(Note 6)\t(864)\t(698)\t(764)\nDepreciation depletion and amortization of tangible assets and mineral interests\t\t(8421)\t(6682)\t(5755)\nOther income\t(Note 7)\t1396\t314\t369\nOther expense\t(Note 7)\t(900)\t(600)\t(554)\nFinancial interest on debt\t\t(465)\t(530)\t(1000)\nFinancial income from marketable securities & cash equivalents\t\t131\t132\t473\nCost of net debt\t(Note 29)\t(334)\t(398)\t(527)\nOther financial income\t(Note 8)\t442\t643\t728\nOther financial expense\t(Note 8)\t(407)\t(345)\t(325)\nEquity in income (loss) of affiliates\t(Note 12)\t1953\t1642\t1721\nIncome taxes\t(Note 9)\t(10228)\t(7751)\t(14146)\nConsolidated net income\t\t10807\t8629\t10953\nGroup share\t\t10571\t8447\t10590\nMinority interests\t\t236\t182\t363\nEarnings per share (€)\t\t4.73\t3.79\t4.74\nFully-diluted earnings per share (€)\t\t4.71\t3.78\t4.71\n", "q10k_tbl_126": "For the year ended December 31 (M€)\t2010\t2009\t2008\nConsolidated net income\t10807\t8629\t10953\nOther comprehensive income\t\t\t\nCurrency translation adjustment\t2231\t(244)\t(722)\nAvailable for sale financial assets\t(100)\t38\t(254)\nCash flow hedge\t(80)\t128\t0\nShare of other comprehensive income of associates net amount\t302\t234\t173\nOther\t(7)\t(5)\t1\nTax effect\t28\t(38)\t30\nTotal other comprehensive income (net amount) (note 17)\t2374\t113\t(772)\nComprehensive income\t13181\t8742\t10181\n- Group share\t12936\t8500\t9852\n- Minority interests\t245\t242\t329\n", "q10k_tbl_127": "As of December 31 (M€)\t\t2010\t2009\t2008\nASSETS\t\t\t\t\nNon-current assets\t\t\t\t\nIntangible assets net\t(Notes 5 & 10)\t8917\t7514\t5341\nProperty plant and equipment net\t(Notes 5 & 11)\t54964\t51590\t46142\nEquity affiliates: investments and loans\t(Note 12)\t11516\t13624\t14668\nOther investments\t(Note 13)\t4590\t1162\t1165\nHedging instruments of non-current financial debt\t(Note 20)\t1870\t1025\t892\nOther non-current assets\t(Note 14)\t3655\t3081\t3044\nTotal non-current assets\t\t85512\t77996\t71252\nCurrent assets\t\t\t\t\nInventories net\t(Note 15)\t15600\t13867\t9621\nAccounts receivable net\t(Note 16)\t18159\t15719\t15287\nOther current assets\t(Note 16)\t7483\t8198\t9642\nCurrent financial assets\t(Note 20)\t1205\t311\t187\nCash and cash equivalents\t(Note 27)\t14489\t11662\t12321\nTotal current assets\t\t56936\t49757\t47058\nAssets classified as held for sale\t(Note 34)\t1270\t0\t0\nTotal assets\t\t143718\t127753\t118310\nLIABILITIES & SHAREHOLDERS' EQUITY\t\t\t\t\nShareholders' equity\t\t\t\t\nCommon shares\t\t5874\t5871\t5930\nPaid-in surplus and retained earnings\t\t60538\t55372\t52947\nCurrency translation adjustment\t\t(2495)\t(5069)\t(4876)\nTreasury shares\t\t(3503)\t(3622)\t(5009)\nTotal shareholders' equity - Group share\t(Note 17)\t60414\t52552\t48992\nMinority interests\t\t857\t987\t958\nTotal shareholders' equity\t\t61271\t53539\t49950\nNon-current liabilities\t\t\t\t\nDeferred income taxes\t(Note 9)\t9947\t8948\t7973\nEmployee benefits\t(Note 18)\t2171\t2040\t2011\nProvisions and other non-current liabilities\t(Note 19)\t9098\t9381\t7858\nTotal non-current liabilities\t\t21216\t20369\t17842\nNon-current financial debt\t(Note 20)\t20783\t19437\t16191\nCurrent liabilities\t\t\t\t\nAccounts payable\t\t18450\t15383\t14815\nOther creditors and accrued liabilities\t(Note 21)\t11989\t11908\t11632\nCurrent borrowings\t(Note 20)\t9653\t6994\t7722\nOther current financial liabilities\t(Note 20)\t159\t123\t158\nTotal current liabilities\t\t40251\t34408\t34327\nLiabilities directly associated with the assets classified as held for sale\t(Note 34)\t197\t0\t0\nTotal liabilities and shareholders' equity\t\t143718\t127753\t118310\n", "q10k_tbl_128": "For the year ended December 31 (M€)\t2010\t2009\t2008\nCASH FLOW FROM OPERATING ACTIVITIES\t\t\t\nConsolidated net income\t10807\t8629\t10953\nDepreciation depletion and amortization\t9117\t7107\t6197\nNon-current liabilities valuation allowances and deferred taxes\t527\t441\t(150)\nImpact of coverage of pension benefit plans\t(60)\t0\t(505)\n(Gains) losses on disposals of assets\t(1046)\t(200)\t(257)\nUndistributed affiliates' equity earnings\t(470)\t(378)\t(311)\n(Increase) decrease in working capital\t(496)\t(3316)\t2571\nOther changes net\t114\t77\t171\nCash flow from operating activities\t18493\t12360\t18669\nCASH FLOW USED IN INVESTING ACTIVITIES\t\t\t\nIntangible assets and property plant and equipment additions\t(13812)\t(11849)\t(11861)\nAcquisitions of subsidiaries net of cash acquired\t(862)\t(160)\t(559)\nInvestments in equity affiliates and other securities\t(654)\t(400)\t(416)\nIncrease in non-current loans\t(945)\t(940)\t(804)\nTotal expenditures\t(16273)\t(13349)\t(13640)\nProceeds from disposals of intangible assets and property plant and equipment\t1534\t138\t130\nProceeds from disposals of subsidiaries net of cash sold\t310\t0\t88\nProceeds from disposals of non-current investments\t1608\t2525\t1233\nRepayment of non-current loans\t864\t418\t1134\nTotal divestments\t4316\t3081\t2585\nCash flow used in investing activities\t(11957)\t(10268)\t(11055)\nCASH FLOW USED IN FINANCING ACTIVITIES\t\t\t\nIssuance (repayment) of shares:\t\t\t\n- Parent company shareholders\t41\t41\t262\n- Treasury shares\t49\t22\t(1189)\n- Minority shareholders\t0\t0\t(4)\nDividends paid:\t\t\t\n- Parent company shareholders\t(5098)\t(5086)\t(4945)\n- Minority shareholders\t(152)\t(189)\t(213)\nOther transactions with minority shareholders\t(429)\t0\t0\nNet issuance (repayment) of non-current debt\t3789\t5522\t3009\nIncrease (decrease) in current borrowings\t(731)\t(3124)\t1437\nIncrease (decrease) in current financial assets and liabilities\t(817)\t(54)\t850\nCash flow used in financing activities\t(3348)\t(2868)\t(793)\nNet increase (decrease) in cash and cash equivalents\t3188\t(776)\t6821\nEffect of exchange rates\t(361)\t117\t(488)\nCash and cash equivalents at the beginning of the period\t11662\t12321\t5988\nCash and cash equivalents at the end of the period\t14489\t11662\t12321\n", "q10k_tbl_129": "\t\t\tPaid-in\t\t\t\t\t\t\n\t\t\tsurplus\t\t\t\t\t\t\n\t\t\tand\tCurrency\t\t\tShareholders'\t\tTotal\n\tCommon shares issued\t\tretained\ttranslation\tTreasury shares\t\tequity-\tMinority\tshareholders'\n(M€)\tNumber\tAmount\tearnings\tadjustment\tNumber\tAmount\tGroup share\tinterests\tequity\nAs of January 1 2008\t2395532097\t5989\t48797\t(4396)\t(151421232)\t(5532)\t44858\t842\t45700\nNet income 2008\t0\t0\t10590\t0\t0\t0\t10590\t363\t10953\nOther comprehensive income (Note 17)\t0\t0\t(258)\t(480)\t0\t0\t(738)\t(34)\t(772)\nComprehensive income\t0\t0\t10332\t(480)\t0\t0\t9852\t329\t10181\nDividend\t0\t0\t(4945)\t0\t0\t0\t(4945)\t(213)\t(5158)\nIssuance of common shares (Note 17)\t6275977\t16\t246\t0\t0\t0\t262\t0\t262\nPurchase of treasury shares\t0\t0\t0\t0\t(27600000)\t(1339)\t(1339)\t0\t(1339)\nSale of treasury shares(a)\t0\t0\t(71)\t0\t5939137\t221\t150\t0\t150\nShare-based payments (Note 25)\t0\t0\t154\t0\t\t\t154\t0\t154\nOther operations with minority interests\t0\t0\t0\t0\t\t\t0\t0\t0\nShare cancellation (Note 17)\t(30000000)\t(75)\t(1566)\t0\t30000000\t1641\t0\t0\t0\nTransactions with shareholders\t(23724023)\t(59)\t(6182)\t0\t8339137\t523\t(5718)\t(213)\t(5931)\nAs of December 31 2008\t2371808074\t5930\t52947\t(4876)\t(143082095)\t(5009)\t48992\t958\t49950\nNet income 2009\t0\t0\t8447\t0\t0\t0\t8447\t182\t8629\nOther comprehensive income (Note 17)\t0\t0\t246\t(193)\t0\t0\t53\t60\t113\nComprehensive income\t0\t0\t8693\t(193)\t0\t0\t8500\t242\t8742\nDividend\t0\t0\t(5086)\t0\t0\t0\t(5086)\t(189)\t(5275)\nIssuance of common shares (Note 17)\t1414810\t3\t38\t0\t0\t0\t41\t0\t41\nPurchase of treasury shares\t0\t0\t0\t0\t0\t0\t0\t0\t0\nSale of treasury shares(a)\t0\t0\t(143)\t0\t2874905\t165\t22\t0\t22\nShare-based payments (Note 25)\t0\t0\t106\t0\t0\t0\t106\t0\t106\nOther operations with minority interests\t0\t0\t(23)\t0\t0\t0\t(23)\t(24)\t(47)\nShare cancellation (Note 17)\t(24800000)\t(62)\t(1160)\t0\t24800000\t1222\t0\t0\t0\nTransactions with shareholders\t(23385190)\t(59)\t(6268)\t0\t27674905\t1387\t(4940)\t(213)\t(5153)\nAs of December 31 2009\t2348422884\t5871\t55372\t(5069)\t(115407190)\t(3622)\t52552\t987\t53539\nNet income 2010\t0\t0\t10571\t0\t0\t0\t10571\t236\t10807\nOther comprehensive income (Note 17)\t0\t0\t(216)\t2581\t0\t0\t2365\t9\t2374\nComprehensive income\t0\t0\t10355\t2581\t0\t0\t12936\t245\t13181\nDividend\t0\t0\t(5098)\t0\t0\t0\t(5098)\t(152)\t(5250)\nIssuance of common shares (Note 17)\t1218047\t3\t38\t0\t0\t0\t41\t0\t41\nPurchase of treasury shares\t0\t0\t0\t0\t0\t0\t0\t0\t0\nSale of treasury shares(a)\t0\t0\t(70)\t0\t2919511\t119\t49\t0\t49\nShare-based payments (Note 25)\t0\t0\t140\t0\t0\t0\t140\t0\t140\nOther operations with minority interests\t0\t0\t(199)\t(7)\t0\t0\t(206)\t(223)\t(429)\nShare cancellation (Note 17)\t0\t0\t0\t0\t0\t0\t0\t0\t0\nTransactions with shareholders\t1218047\t3\t(5189)\t(7)\t2919511\t119\t(5074)\t(375)\t(5449)\nAs of December 31 2010\t2349640931\t5874\t60538\t(2495)\t(112487679)\t(3503)\t60414\t857\t61271\n", "q10k_tbl_130": "0\tTOTAL completed in September 2010 an agreement for the sale to BP and Hess of its interests in the Valhall (15.72%) and Hod (25%) fields in the Norwegian North Sea for an amount of €800 million.\n0\tTOTAL signed in September 2010 an agreement with Santos and Petronas to acquire a 20% interest in the GLNG project in Australia. Upon completion of this transaction finalised in October 2010 the project brings together Santos (45% operator) Petronas (35%) and TOTAL (20%).\n", "q10k_tbl_131": "0\tIn August 2008 TOTAL acquired the Dutch company Goal Petroleum BV. The acquisition cost amounted to €349 million. This cost essentially represented the value of the company's mineral interests that have been recognized as intangible assets on the face of the Consolidated Balance Sheet for €292 million.\n\tGoal Petroleum BV is fully consolidated in TOTAL's Consolidated Financial Statements. Its contribution to the consolidated net income for fiscal year 2008 was not material.\n0\tPursuant to the agreements signed between the partners in November 2008 the Group's participation in the Kashagan field decreased from 18.52% to 16.81%.\n", "q10k_tbl_132": "For the year ended December 31 2010\t\t\t\t\t\t\n(M€)\tUpstream\tDownstream\tChemicals\tCorporate\tIntercompany\tTotal\nNon-Group sales\t18527\t123245\t17490\t7\t0\t159269\nIntersegment sales\t22540\t4693\t981\t186\t(28400)\t0\nExcise taxes\t0\t(18793)\t0\t0\t0\t(18793)\nRevenues from sales\t41067\t109145\t18471\t193\t(28400)\t140476\nOperating expenses\t(18271)\t(105660)\t(16974)\t(665)\t28400\t(113170)\nDepreciation depletion and amortization of tangible assets and mineral interests\t(5346)\t(2503)\t(533)\t(39)\t0\t(8421)\nOperating income\t17450\t982\t964\t(511)\t0\t18885\nEquity in income (loss) of affiliates and other items\t1533\t141\t215\t595\t0\t2484\nTax on net operating income\t(10131)\t(201)\t(267)\t263\t0\t(10336)\nNet operating income\t8852\t922\t912\t347\t0\t11033\nNet cost of net debt\t\t\t\t\t\t(226)\nMinority interests\t\t\t\t\t\t(236)\nNet income\t\t\t\t\t\t10571\n", "q10k_tbl_133": "For the year ended December 31 2010 (adjustments(a))\t\t\t\t\t\t\n(M€)\tUpstream\tDownstream\tChemicals\tCorporate\tIntercompany\tTotal\nNon-Group sales\t\t\t\t\t\t\nIntersegment sales\t\t\t\t\t\t\nExcise taxes\t\t\t\t\t\t\nRevenues from sales\t\t\t\t\t\t\nOperating expenses\t0\t923\t92\t0\t\t1015\nDepreciation depletion and amortization of tangible assets and mineral interests\t(203)\t(1192)\t(21)\t0\t\t(1416)\nOperating income(b)\t(203)\t(269)\t71\t0\t\t(401)\nEquity in income (loss) of affiliates and other items(c)\t183\t(126)\t(16)\t227\t\t268\nTax on net operating income\t275\t149\t0\t(6)\t\t418\nNet operating income(b)\t255\t(246)\t55\t221\t\t285\nNet cost of net debt\t\t\t\t\t\t0\nMinority interests\t\t\t\t\t\t(2)\nNet income\t\t\t\t\t\t283\n", "q10k_tbl_134": "For the year ended December 31 2010 (adjusted)\t\t\t\t\t\t\n(M€)(a)\tUpstream\tDownstream\tChemicals\tCorporate\tIntercompany\tTotal\nNon-Group sales\t18527\t123245\t17490\t7\t0\t159269\nIntersegment sales\t22540\t4693\t981\t186\t(28400)\t0\nExcise taxes\t0\t(18793)\t0\t0\t0\t(18793)\nRevenues from sales\t41067\t109145\t18471\t193\t(28400)\t140476\nOperating expenses\t(18271)\t(106583)\t(17066)\t(665)\t28400\t(114185)\nDepreciation depletion and amortization of tangible assets and mineral interests\t(5143)\t(1311)\t(512)\t(39)\t0\t(7005)\nAdjusted operating income\t17653\t1251\t893\t(511)\t0\t19286\nEquity in income (loss) of affiliates and other items\t1350\t267\t231\t368\t0\t2216\nTax on net operating income\t(10406)\t(350)\t(267)\t269\t0\t(10754)\nAdjusted net operating income\t8597\t1168\t857\t126\t0\t10748\nNet cost of net debt\t\t\t\t\t\t(226)\nMinority interests\t\t\t\t\t\t(234)\nAdjusted net income\t\t\t\t\t\t10288\nAdjusted fully-diluted earnings per share (€)\t\t\t\t\t\t4.58\n", "q10k_tbl_135": "For the year ended December 31 2010\t\t\t\t\t\t\n(M€)\tUpstream\tDownstream\tChemicals\tCorporate\tIntercompany\tTotal\nTotal expenditures\t13208\t2343\t641\t81\t\t16273\nTotal divestments\t2067\t499\t347\t1403\t\t4316\nCash flow from operating activities\t15573\t1441\t934\t545\t\t18493\nBalance sheet as of December 31 2010\t\t\t\t\t\t\nProperty plant and equipment intangible assets net\t50565\t8675\t4388\t253\t\t63881\nInvestments in equity affiliates\t5002\t2782\t1349\t0\t\t9133\nLoans to equity affiliates and other non-current assets\t4184\t1366\t979\t4099\t\t10628\nWorking capital\t(363)\t9154\t2223\t(211)\t\t10803\nProvisions and other non-current liabilities\t(16076)\t(2328)\t(1631)\t(1181)\t\t(21216)\nAssets and liabilities classified as held for sale\t660\t0\t413\t0\t\t1073\nCapital Employed (balance sheet)\t43972\t19649\t7721\t2960\t\t74302\nLess inventory valuation effect\t0\t(4088)\t(409)\t1061\t\t(3436)\nCapital Employed (Business segment information)\t43972\t15561\t7312\t4021\t\t70866\nROACE as a percentage\t21%\t8%\t12%\t\t\t16%\n", "q10k_tbl_136": "For the year ended December 31 2009\t\t\t\t\t\t\n(M€)\tUpstream\tDownstream\tChemicals\tCorporate\tIntercompany\tTotal\nNon-Group sales\t16072\t100518\t14726\t11\t0\t131327\nIntersegment sales\t15958\t3786\t735\t156\t(20635)\t0\nExcise taxes\t0\t(19174)\t0\t0\t0\t(19174)\nRevenues from sales\t32030\t85130\t15461\t167\t(20635)\t112153\nOperating expenses\t(14752)\t(81281)\t(14293)\t(656)\t20635\t(90347)\nDepreciation depletion and amortization of tangible assets and mineral interests\t(4420)\t(1612)\t(615)\t(35)\t0\t(6682)\nOperating income\t12858\t2237\t553\t(524)\t0\t15124\nEquity in income (loss) of affiliates and other items\t846\t169\t(58)\t697\t0\t1654\nTax on net operating income\t(7486)\t(633)\t(92)\t326\t0\t(7885)\nNet operating income\t6218\t1773\t403\t499\t0\t8893\nNet cost of net debt\t\t\t\t\t\t(264)\nMinority interests\t\t\t\t\t\t(182)\nNet income\t\t\t\t\t\t8447\n", "q10k_tbl_137": "For the year ended December 31 2009 (adjustments(a))\t\t\t\t\t\t\n(M€)\tUpstream\tDownstream\tChemicals\tCorporate\tIntercompany\tTotal\nNon-Group sales\t\t\t\t\t\t\nIntersegment sales\t\t\t\t\t\t\nExcise taxes\t\t\t\t\t\t\nRevenues from sales\t\t\t\t\t\t\nOperating expenses\t(17)\t1558\t344\t0\t\t1885\nDepreciation depletion and amortization of tangible assets and mineral interests\t(4)\t(347)\t(40)\t0\t\t(391)\nOperating income(b)\t(21)\t1211\t304\t0\t\t1494\nEquity in income (loss) of affiliates and other items(c)\t(160)\t22\t(123)\t(117)\t\t(378)\nTax on net operating income\t17\t(413)\t(50)\t(3)\t\t(449)\nNet operating income(b)\t(164)\t820\t131\t(120)\t\t667\nNet cost of net debt\t\t\t\t\t\t0\nMinority interests\t\t\t\t\t\t(4)\nNet income\t\t\t\t\t\t663\n", "q10k_tbl_138": "For the year ended December 31 2009\t\t\t\t\t\t\n(adjusted)\t\t\t\t\t\t\n(M€)(a)\tUpstream\tDownstream\tChemicals\tCorporate\tIntercompany\tTotal\nNon-Group sales\t16072\t100518\t14726\t11\t0\t131327\nIntersegment sales\t15958\t3786\t735\t156\t(20635)\t0\nExcise taxes\t0\t(19174)\t0\t0\t0\t(19174)\nRevenues from sales\t32030\t85130\t15461\t167\t(20635)\t112153\nOperating expenses\t(14735)\t(82839)\t(14637)\t(656)\t20635\t(92232)\nDepreciation depletion and amortization of tangible assets and mineral interests\t(4416)\t(1265)\t(575)\t(35)\t0\t(6291)\nAdjusted operating income\t12879\t1026\t249\t(524)\t0\t13630\nEquity in income (loss) of affiliates and other items\t1006\t147\t65\t814\t0\t2032\nTax on net operating income\t(7503)\t(220)\t(42)\t329\t0\t(7436)\nAdjusted net operating income\t6382\t953\t272\t619\t0\t8226\nNet cost of net debt\t\t\t\t\t\t(264)\nMinority interests\t\t\t\t\t\t(178)\nAdjusted net income\t\t\t\t\t\t7784\nAdjusted fully-diluted earnings per share (€)\t\t\t\t\t\t3.48\n", "q10k_tbl_139": "For the year ended December 31 2009\t\t\t\t\t\t\n(M€)\tUpstream\tDownstream\tChemicals\tCorporate\tIntercompany\tTotal\nTotal expenditures\t9855\t2771\t631\t92\t\t13349\nTotal divestments\t398\t133\t47\t2503\t\t3081\nCash flow from operating activities\t10200\t1164\t1082\t(86)\t\t12360\nBalance sheet as of December 31 2009\t\t\t\t\t\t\nProperty plant and equipment intangible assets net\t43997\t9588\t5248\t271\t\t59104\nInvestments in equity affiliates\t4260\t2110\t652\t4235\t\t11257\nLoans to equity affiliates and other non-current assets\t3844\t1369\t850\t547\t\t6610\nWorking capital\t660\t7624\t2151\t58\t\t10493\nProvisions and other non-current liabilities\t(15364)\t(2190)\t(1721)\t(1094)\t\t(20369)\nAssets and liabilities classified as held for sale\t0\t0\t0\t0\t\t0\nCapital Employed (balance sheet)\t37397\t18501\t7180\t4017\t\t67095\nLess inventory valuation effect\t0\t(3202)\t(282)\t840\t\t(2644)\nCapital Employed (Business segment information)\t37397\t15299\t6898\t4857\t\t64451\nROACE as a percentage\t18%\t7%\t4%\t\t\t13%\n", "q10k_tbl_140": "For the year ended December 31 2008\t\t\t\t\t\t\n(M€)\tUpstream\tDownstream\tChemicals\tCorporate\tIntercompany\tTotal\nNon-Group sales\t24256\t135524\t20150\t46\t0\t179976\nIntersegment sales\t25132\t5574\t1252\t120\t(32078)\t0\nExcise taxes\t0\t(19645)\t0\t0\t0\t(19645)\nRevenues from sales\t49388\t121453\t21402\t166\t(32078)\t160331\nOperating expenses\t(21915)\t(119425)\t(20942)\t(685)\t32078\t(130889)\nDepreciation depletion and amortization of tangible assets and mineral interests\t(4005)\t(1202)\t(518)\t(30)\t0\t(5755)\nOperating income\t23468\t826\t(58)\t(549)\t0\t23687\nEquity in income (loss) of affiliates and other items\t1541\t(158)\t(34)\t590\t0\t1939\nTax on net operating income\t(14563)\t(143)\t76\t315\t0\t(14315)\nNet operating income\t10446\t525\t(16)\t356\t0\t11311\nNet cost of net debt\t\t\t\t\t\t(358)\nMinority interests\t\t\t\t\t\t(363)\nNet income\t\t\t\t\t\t10590\n", "q10k_tbl_141": "For the year ended December 31 2008 (adjustments(a))\t\t\t\t\t\t\n(M€)\tUpstream\tDownstream\tChemicals\tCorporate\tIntercompany\tTotal\nNon-Group sales\t\t\t\t\t\t\nIntersegment sales\t\t\t\t\t\t\nExcise taxes\t\t\t\t\t\t\nRevenues from sales\t\t\t\t\t\t\nOperating expenses\t0\t(2776)\t(925)\t0\t\t(3701)\nDepreciation depletion and amortization of tangible assets and mineral interest\t(171)\t0\t(6)\t0\t\t(177)\nOperating income(b)\t(171)\t(2776)\t(931)\t0\t\t(3878)\nEquity in income (loss) of affiliates and other items(c)\t(164)\t(195)\t(82)\t(345)\t\t(786)\nTax on net operating income\t57\t927\t329\t(2)\t\t1311\nNet operating income(b)\t(278)\t(2044)\t(684)\t(347)\t\t(3353)\nNet cost of net debt\t\t\t\t\t\t0\nMinority interests\t\t\t\t\t\t23\nNet income\t\t\t\t\t\t(3330)\n", "q10k_tbl_142": "For the year ended December 31 2008\t\t\t\t\t\t\n(adjusted)\t\t\t\t\t\t\n(M€)(a)\tUpstream\tDownstream\tChemicals\tCorporate\tIntercompany\tTotal\nNon-Group sales\t24256\t135524\t20150\t46\t0\t179976\nIntersegment sales\t25132\t5574\t1252\t120\t(32078)\t0\nExcise taxes\t0\t(19645)\t0\t0\t0\t(19645)\nRevenues from sales\t49388\t121453\t21402\t166\t(32078)\t160331\nOperating expenses\t(21915)\t(116649)\t(20017)\t(685)\t32078\t(127188)\nDepreciation depletion and amortization of tangible assets and mineral interests\t(3834)\t(1202)\t(512)\t(30)\t0\t(5578)\nAdjusted operating income\t23639\t3602\t873\t(549)\t0\t27565\nEquity in income (loss) of affiliates and other items\t1705\t37\t48\t935\t0\t2725\nTax on net operating income\t(14620)\t(1070)\t(253)\t317\t0\t(15626)\nAdjusted net operating income\t10724\t2569\t668\t703\t0\t14664\nNet cost of net debt\t\t\t\t\t\t(358)\nMinority interests\t\t\t\t\t\t(386)\nAdjusted net income\t\t\t\t\t\t13920\nAdjusted fully-diluted earnings per share (€)\t\t\t\t\t\t6.20\n", "q10k_tbl_143": "For the year ended December 31 2008\t\t\t\t\t\t\n(M€)\tUpstream\tDownstream\tChemicals\tCorporate\tIntercompany\tTotal\nTotal expenditures\t10017\t2418\t1074\t131\t\t13640\nTotal divestments\t1130\t216\t53\t1186\t\t2585\nCash flow from operating activities\t13765\t3111\t920\t873\t\t18669\nBalance sheet as of December 31 2008\t\t\t\t\t\t\nProperty plant and equipment intangible assets net\t37090\t8823\t5323\t247\t\t51483\nInvestments in equity affiliates\t3892\t1958\t677\t6134\t\t12661\nLoans to equity affiliates and other non-current assets\t3739\t1170\t762\t545\t\t6216\nWorking capital\t570\t5317\t2348\t(132)\t\t8103\nProvisions and other non-current liabilities\t(12610)\t(2191)\t(1903)\t(1138)\t\t(17842)\nAssets and liabilities classified as held for sale\t0\t0\t0\t0\t\t0\nCapital Employed (balance sheet)\t32681\t15077\t7207\t5656\t\t60621\nLess inventory valuation effect\t0\t(1454)\t(46)\t387\t\t(1113)\nCapital Employed (Business segment information)\t32681\t13623\t7161\t6043\t\t59508\nROACE as a percentage\t36%\t20%\t9%\t\t\t26%\n", "q10k_tbl_144": "\t\t\tConsolidated\nFor the year ended December 31 2010\t\t\tstatement of\n(M€)\tAdjusted\tAdjustments(a)\tincome\nSales\t159269\t0\t159269\nExcise taxes\t(18793)\t0\t(18793)\nRevenues from sales\t140476\t0\t140476\nPurchases net of inventory variation\t(94286)\t1115\t(93171)\nOther operating expenses\t(19035)\t(100)\t(19135)\nExploration costs\t(864)\t0\t(864)\nDepreciation depletion and amortization of tangible assets and mineral interests\t(7005)\t(1416)\t(8421)\nOther income\t524\t872\t1396\nOther expense\t(346)\t(554)\t(900)\nFinancial interest on debt\t(465)\t0\t(465)\nFinancial income from marketable securities & cash equivalents\t131\t0\t131\nCost of net debt\t(334)\t0\t(334)\nOther financial income\t442\t0\t442\nOther financial expense\t(407)\t0\t(407)\nEquity in income (loss) of affiliates\t2003\t(50)\t1953\nIncome taxes\t(10646)\t418\t(10228)\nConsolidated net income\t10522\t285\t10807\nGroup share\t10288\t283\t10571\nMinority interests\t234\t2\t236\n", "q10k_tbl_145": "\t\t\tConsolidated\nFor the year ended December 31 2009\t\t\tstatement of\n(M€)\tAdjusted\tAdjustments(a)\tincome\nSales\t131327\t0\t131327\nExcise taxes\t(19174)\t0\t(19174)\nRevenues from sales\t112153\t0\t112153\nPurchases net of inventory variation\t(73263)\t2205\t(71058)\nOther operating expenses\t(18271)\t(320)\t(18591)\nExploration costs\t(698)\t0\t(698)\nDepreciation depletion and amortization of tangible assets and mineral interests\t(6291)\t(391)\t(6682)\nOther income\t131\t183\t314\nOther expense\t(315)\t(285)\t(600)\nFinancial interest on debt\t(530)\t0\t(530)\nFinancial income from marketable securities & cash equivalents\t132\t0\t132\nCost of net debt\t(398)\t0\t(398)\nOther financial income\t643\t0\t643\nOther financial expense\t(345)\t0\t(345)\nEquity in income (loss) of affiliates\t1918\t(276)\t1642\nIncome taxes\t(7302)\t(449)\t(7751)\nConsolidated net income\t7962\t667\t8629\nGroup share\t7784\t663\t8447\nMinority interests\t178\t4\t182\n", "q10k_tbl_146": "\t\t\tConsolidated\nFor the year ended December 31 2008\t\t\tstatement of\n(M€)\tAdjusted\tAdjustments(a)\tincome\nSales\t179976\t0\t179976\nExcise taxes\t(19645)\t0\t(19645)\nRevenues from sales\t160331\t0\t160331\nPurchases net of inventory variation\t(107521)\t(3503)\t(111024)\nOther operating expenses\t(18903)\t(198)\t(19101)\nExploration costs\t(764)\t0\t(764)\nDepreciation depletion and amortization of tangible assets and mineral interests\t(5578)\t(177)\t(5755)\nOther income\t153\t216\t369\nOther expense\t(147)\t(407)\t(554)\nFinancial interest on debt\t(1000)\t0\t(1000)\nFinancial income from marketable securities & cash equivalents\t473\t0\t473\nCost of net debt\t(527)\t0\t(527)\nOther financial income\t728\t0\t728\nOther financial expense\t(325)\t0\t(325)\nEquity in income (loss) of affiliates\t2316\t(595)\t1721\nIncome taxes\t(15457)\t1311\t(14146)\nConsolidated net income\t14306\t(3353)\t10953\nGroup share\t13920\t(3330)\t10590\nMinority interests\t386\t(23)\t363\n", "q10k_tbl_147": "For the year ended December 31 2010 (M€)\tUpstream\tDownstream\tChemicals\tCorporate\tTotal\nInventory valuation effect\t0\t863\t130\t0\t993\nRestructuring charges\t0\t0\t0\t0\t0\nAsset impairment charges\t(203)\t(1192)\t(21)\t0\t(1416)\nOther items\t0\t60\t(38)\t0\t22\nTotal\t(203)\t(269)\t71\t0\t(401)\n", "q10k_tbl_148": "For the year ended December 31 2010 (M€)\tUpstream\tDownstream\tChemicals\tCorporate\tTotal\nInventory valuation effect\t0\t635\t113\t0\t748\nTOTAL's equity share of adjustments related to Sanofi-Aventis\t0\t0\t0\t(81)\t(81)\nRestructuring charges\t0\t(12)\t(41)\t0\t(53)\nAsset impairment charges\t(297)\t(913)\t(14)\t0\t(1224)\nGains (losses) on disposals of assets\t589\t122\t33\t302\t1046\nOther items\t(37)\t(83)\t(33)\t0\t(153)\nTotal\t255\t(251)\t58\t221\t283\n", "q10k_tbl_149": "For the year ended December 31 2009 (M€)\tUpstream\tDownstream\tChemicals\tCorporate\tTotal\nInventory valuation effect\t0\t1816\t389\t0\t2205\nRestructuring charges\t0\t0\t0\t0\t0\nAsset impairment charges\t(4)\t(347)\t(40)\t0\t(391)\nOther items\t(17)\t(258)\t(45)\t0\t(320)\nTotal\t(21)\t1211\t304\t0\t1494\n", "q10k_tbl_150": "For the year ended December 31 2009 (M€)\tUpstream\tDownstream\tChemicals\tCorporate\tTotal\nInventory valuation effect\t0\t1279\t254\t0\t1533\nTOTAL's equity share of adjustments related to Sanofi-Aventis\t0\t0\t0\t(300)\t(300)\nRestructuring charges\t0\t(27)\t(102)\t0\t(129)\nAsset impairment charges\t(52)\t(253)\t(28)\t0\t(333)\nGains (losses) on disposals of assets\t0\t0\t0\t179\t179\nOther items\t(112)\t(182)\t7\t0\t(287)\nTotal\t(164)\t817\t131\t(121)\t663\n", "q10k_tbl_151": "For the year ended December 31 2008 (M€)\tUpstream\tDownstream\tChemicals\tCorporate\tTotal\nInventory valuation effect\t0\t(2776)\t(727)\t0\t(3503)\nRestructuring charges\t0\t0\t0\t0\t0\nAsset impairment charges\t(171)\t0\t(6)\t0\t(177)\nOther items\t0\t0\t(198)\t0\t(198)\nTotal\t(171)\t(2776)\t(931)\t0\t(3878)\n", "q10k_tbl_152": "For the year ended December 31 2008 (M€)\tUpstream\tDownstream\tChemicals\tCorporate\tTotal\nInventory valuation effect\t0\t(1949)\t(503)\t0\t(2452)\nTOTAL's equity share of adjustments related to Sanofi-Aventis\t0\t0\t0\t(393)\t(393)\nRestructuring charges\t0\t(47)\t(22)\t0\t(69)\nAsset impairment charges\t(172)\t(26)\t(7)\t0\t(205)\nGains (losses) on disposals of assets\t130\t0\t0\t84\t214\nOther items\t(236)\t0\t(151)\t(38)\t(425)\nTotal\t(278)\t(2022)\t(683)\t(347)\t(3330)\n", "q10k_tbl_153": "0\tThe recoverable amount of CGUs has been based on their value in use as defined in Note 1 paragraph L to the Consolidated Financial Statements \"Impairment of long-lived assets\";\n0\tFuture cash flows have been determined with the assumptions in the long-term plan of the Group. These assumptions (including future prices of products supply and demand for products future production volumes) represent the best estimate by management of the Group of all economic conditions during the remaining life of assets;\n0\tFuture cash flows based on the long-term plan are prepared over a period consistent with the life of the assets within the CGU. They are prepared post-tax and include specific risks attached to CGU assets. They are discounted using a 8% post-tax discount rate this rate being a weighted-average capital cost estimated from historical market data. This rate has been applied consistently for the years ending in 2008 2009 and 2010;\n0\tValue in use calculated by discounting the above post-tax cash flows using a 8% post-tax discount rate is not materially different from value in use calculated by discounting pre-tax cash flows using a pre-tax discount rate determined by an iterative computation from the post-tax value in use. These pre-tax discount rates are in a range from 9% to 12% in 2010.\n", "q10k_tbl_154": "\t\tRest of\tNorth\t\tRest of\t\n(M€)\tFrance\tEurope\tAmerica\tAfrica\tthe world\tTotal\nFor the year ended December 31 2010\t\t\t\t\t\t\nNon-Group sales\t36820\t72636\t12432\t12561\t24820\t159269\nProperty plant and equipment intangible assets net\t5666\t14568\t9584\t20166\t13897\t63881\nCapital expenditures\t1062\t2629\t3626\t4855\t4101\t16273\nFor the year ended December 31 2009\t\t\t\t\t\t\nNon-Group sales\t32437\t60140\t9515\t9808\t19427\t131327\nProperty plant and equipment intangible assets net\t6973\t15218\t8112\t17312\t11489\t59104\nCapital expenditures\t1189\t2502\t1739\t4651\t3268\t13349\nFor the year ended December 31 2008\t\t\t\t\t\t\nNon-Group sales\t43616\t82761\t14002\t12482\t27115\t179976\nProperty plant and equipment intangible assets net\t7260\t13485\t5182\t15460\t10096\t51483\nCapital expenditures\t1997\t2962\t1255\t4500\t2926\t13640\n", "q10k_tbl_155": "For the year ended December 31 (M€)\t2010\t2009\t2008\nPurchases net of inventory variation(a)\t(93171)\t(71058)\t(111024)\nExploration costs\t(864)\t(698)\t(764)\nOther operating expenses(b)\t(19135)\t(18591)\t(19101)\nof which non-current operating liabilities (allowances) reversals\t387\t515\t459\nof which current operating liabilities (allowances) reversals\t(101)\t(43)\t(29)\nOperating expenses\t(113170)\t(90347)\t(130889)\n", "q10k_tbl_156": "For the year ended December 31 (M€)\t2010\t2009\t2008\nGains (losses) on disposal of assets\t1117\t200\t257\nForeign exchange gains\t0\t0\t112\nOther\t279\t114\t0\nOther income\t1396\t314\t369\nForeign exchange losses\t0\t(32)\t0\nAmortization of other intangible assets (excl. mineral interests)\t(267)\t(142)\t(162)\nOther\t(633)\t(426)\t(392)\nOther expense\t(900)\t(600)\t(554)\n", "q10k_tbl_157": "As of December 31 (M€)\t2010\t2009\t2008\nDividend income on non-consolidated subsidiaries\t255\t210\t238\nCapitalized financial expenses\t113\t117\t271\nOther\t74\t316\t219\nOther financial income\t442\t643\t728\nAccretion of asset retirement obligations\t(338)\t(283)\t(229)\nOther\t(69)\t(62)\t(96)\nOther financial expense\t(407)\t(345)\t(325)\n", "q10k_tbl_158": "For the year ended December 31 (M€)\t2010\t2009\t2008\nCurrent income taxes\t(9934)\t(7213)\t(14117)\nDeferred income taxes\t(294)\t(538)\t(29)\nTotal income taxes\t(10228)\t(7751)\t(14146)\n", "q10k_tbl_159": "As of December 31 (M€)\t2010\t2009\t2008\nNet operating losses and tax carry forwards\t1145\t1114\t1031\nEmployee benefits\t535\t517\t519\nOther temporary non-deductible provisions\t2757\t2184\t2075\nGross deferred tax assets\t4437\t3815\t3625\nValuation allowance\t(576)\t(484)\t(475)\nNet deferred tax assets\t3861\t3331\t3150\nExcess tax over book depreciation\t(10966)\t(9791)\t(8836)\nOther temporary tax deductions\t(1339)\t(1179)\t(1171)\nGross deferred tax liability\t(12305)\t(10970)\t(10007)\nNet deferred tax liability\t(8444)\t(7639)\t(6857)\n", "q10k_tbl_160": "As of December 31 (M€)\t2010\t2009\t2008\nDeferred tax assets non-current (note 14)\t1378\t1164\t1010\nDeferred tax assets current (note 16)\t151\t214\t206\nDeferred tax liabilities non-current\t(9947)\t(8948)\t(7973)\nDeferred tax liabilities current\t(26)\t(69)\t(100)\nNet amount\t(8444)\t(7639)\t(6857)\n", "q10k_tbl_161": "As of December 31 (M€)\t2010\t2009\t2008\nOpening balance\t(7639)\t(6857)\t(7251)\nDeferred tax on income\t(294)\t(538)\t(29)\nDeferred tax on shareholders' equity(a)\t28\t(38)\t30\nChanges in scope of consolidation\t(59)\t(1)\t(1)\nCurrency translation adjustment\t(480)\t(205)\t394\nClosing balance\t(8444)\t(7639)\t(6857)\n", "q10k_tbl_162": "For the year ended December 31 (M€)\t2010\t2009\t2008\nConsolidated net income\t10807\t8629\t10953\nProvision for income taxes\t10228\t7751\t14146\nPre-tax income\t21035\t16380\t25099\nFrench statutory tax rate\t34.43%\t34.43%\t34.43%\nTheoretical tax charge\t(7242)\t(5640)\t(8642)\nDifference between French and foreign income tax rates\t(4921)\t(3214)\t(6326)\nTax effect of equity in income (loss) of affiliates\t672\t565\t593\nPermanent differences\t1375\t597\t315\nAdjustments on prior years income taxes\t(45)\t(47)\t12\nAdjustments on deferred tax related to changes in tax rates\t2\t(1)\t(31)\nChanges in valuation allowance of deferred tax assets\t(65)\t(6)\t(63)\nOther\t(4)\t(5)\t(4)\nNet provision for income taxes\t(10228)\t(7751)\t(14146)\n", "q10k_tbl_163": "As of December 31 (M€)\t2010\t\t2009\t\t2008\t\n\tBasis\tTax\tBasis\tTax\tBasis\tTax\n2009\t0\t0\t0\t0\t233\t115\n2010\t0\t0\t258\t126\t167\t79\n2011\t225\t110\t170\t83\t93\t42\n2012\t177\t80\t121\t52\t61\t19\n2013(a)\t146\t59\t133\t43\t1765\t587\n2014(b)\t1807\t602\t1804\t599\t0\t0\n2015 and after\t190\t62\t0\t0\t0\t0\nUnlimited\t774\t232\t661\t211\t560\t189\nTotal\t3319\t1145\t3147\t1114\t2879\t1031\n", "q10k_tbl_164": "\t\tAmortization\t\n\t\tand\t\nAs of December 31 2010 (M€)\tCost\timpairment\tNet\nGoodwill\t1498\t(596)\t902\nProved and unproved mineral interests\t10099\t(2712)\t7387\nOther intangible assets\t2803\t(2175)\t628\nTotal intangible assets\t14400\t(5483)\t8917\n", "q10k_tbl_165": "\t\tAmortization\t\n\t\tand\t\nAs of December 31 2009 (M€)\tCost\timpairment\tNet\nGoodwill\t1776\t(614)\t1162\nProved and unproved mineral interests\t8204\t(2421)\t5783\nOther intangible assets\t2712\t(2143)\t569\nTotal intangible assets\t12692\t(5178)\t7514\n", "q10k_tbl_166": "\t\tAmortization\t\n\t\tand\t\nAs of December 31 2008 (M€)\tCost\timpairment\tNet\nGoodwill\t1690\t(616)\t1074\nProved and unproved mineral interests\t6010\t(2268)\t3742\nOther intangible assets\t2519\t(1994)\t525\nTotal intangible assets\t10219\t(4878)\t5341\n", "q10k_tbl_167": "\t\t\t\tAmortization\tCurrency\t\t\n\tNet amount as of\t\t\tand\ttranslation\t\tNet amount as of\n(M€)\tJanuary 1\tAcquisitions\tDisposals\timpairment\tadjustment\tOther\tDecember 31\n2010\t7514\t2466\t(62)\t(553)\t491\t(939)\t8917\n2009\t5341\t629\t(64)\t(345)\t2\t1951\t7514\n2008\t4650\t404\t(3)\t(259)\t(93)\t642\t5341\n", "q10k_tbl_168": "\tNet goodwill as of\t\t\t\tNet goodwill as of\n(M€)\tJanuary 1 2010\tIncreases\tImpairments\tOther\tDecember 31 2010\nUpstream\t78\t0\t0\t0\t78\nDownstream\t202\t22\t(88)\t(54)\t82\nChemicals\t857\t0\t0\t(140)\t717\nCorporate\t25\t0\t0\t0\t25\nTotal\t1162\t22\t(88)\t(194)\t902\n", "q10k_tbl_169": "\t\tDepreciation\t\n\t\tand\t\nAs of December 31 2010 (M€)\tCost\timpairment\tNet\nUpstream properties\t\t\t\nProved properties\t77183\t(50582)\t26601\nUnproved properties\t347\t(1)\t346\nWork in progress\t14712\t(37)\t14675\nSubtotal\t92242\t(50620)\t41622\nOther property plant and equipment\t\t\t\nLand\t1304\t(393)\t911\nMachinery plant and equipment (including transportation equipment)\t23831\t(17010)\t6821\nBuildings\t6029\t(3758)\t2271\nWork in progress\t2350\t(488)\t1862\nOther\t6164\t(4687)\t1477\nSubtotal\t39678\t(26336)\t13342\nTotal property plant and equipment\t131920\t(76956)\t54964\n", "q10k_tbl_170": "\t\tDepreciation\t\n\t\tand\t\nAs of December 31 2009 (M€)\tCost\timpairment\tNet\nUpstream properties\t\t\t\nProved properties\t71082\t(44718)\t26364\nUnproved properties\t182\t(1)\t181\nWork in progress\t10351\t(51)\t10300\nSubtotal\t81615\t(44770)\t36845\nOther property plant and equipment\t\t\t\nLand\t1458\t(435)\t1023\nMachinery plant and equipment (including transportation equipment)\t22927\t(15900)\t7027\nBuildings\t6142\t(3707)\t2435\nWork in progress\t2774\t(155)\t2619\nOther\t6506\t(4865)\t1641\nSubtotal\t39807\t(25062)\t14745\nTotal property plant and equipment\t121422\t(69832)\t51590\n", "q10k_tbl_171": "\t\tDepreciation\t\n\t\tand\t\nAs of December 31 2008 (M€)\tCost\timpairment\tNet\nUpstream properties\t\t\t\nProved properties\t61727\t(39315)\t22412\nUnproved properties\t106\t(1)\t105\nWork in progress\t9586\t0\t9586\nSubtotal\t71419\t(39316)\t32103\nOther property plant and equipment\t\t\t\nLand\t1446\t(429)\t1017\nMachinery plant and equipment (including transportation equipment)\t21734\t(14857)\t6877\nBuildings\t5739\t(3441)\t2298\nWork in progress\t2226\t(10)\t2216\nOther\t6258\t(4627)\t1631\nSubtotal\t37403\t(23364)\t14039\nTotal property plant and equipment\t108822\t(62680)\t46142\n", "q10k_tbl_172": "\tNet amount\t\t\tDepreciation\tCurrency\t\tNet amount\n\tas of\t\t\tand\ttranslation\t\tas of\n(M€)\tJanuary 1\tAcquisitions\tDisposals\timpairment\tadjustment\tOther\tDecember 31\n2010\t51590\t11346\t(1269)\t(8564)\t2974\t(1113)\t54964\n2009\t46142\t11212\t(65)\t(6765)\t397\t669\t51590\n2008\t41467\t11442\t(102)\t(5941)\t(1151)\t427\t46142\n", "q10k_tbl_173": "\t\tDepreciation\t\n\t\tand\t\nAs of December 31 2010 (M€)\tCost\timpairment\tNet\nMachinery plant and equipment\t480\t(332)\t148\nBuildings\t54\t(24)\t30\nOther\t0\t0\t0\nTotal\t534\t(356)\t178\n", "q10k_tbl_174": "\t\tDepreciation\t\n\t\tand\t\nAs of December 31 2009 (M€)\tCost\timpairment\tNet\nMachinery plant and equipment\t548\t(343)\t205\nBuildings\t60\t(30)\t30\nOther\t0\t0\t0\nTotal\t608\t(373)\t235\n", "q10k_tbl_175": "\t\tDepreciation\t\n\t\tand\t\nAs of December 31 2008 (M€)\tCost\timpairment\tNet\nMachinery plant and equipment\t558\t(316)\t242\nBuildings\t35\t(28)\t7\nOther\t0\t0\t0\nTotal\t593\t(344)\t249\n", "q10k_tbl_176": "Equity value (M€)\tAs of December 31\t\t\t\t\t\n\t2010\t2009\t2008\t2010\t2009\t2008\n\t% owned\t\t\tequity value\t\t\nNLNG\t15.00%\t15.00%\t15.00%\t1108\t1136\t1135\nPetroCedeño - EM\t30.32%\t30.32%\t30.32%\t1136\t874\t760\nCEPSA (Upstream share)\t48.83%\t48.83%\t48.83%\t340\t385\t403\nAngola LNG Ltd.\t13.60%\t13.60%\t13.60%\t710\t490\t326\nQatargas\t10.00%\t10.00%\t10.00%\t85\t83\t251\nSociété du Terminal Méthanier de Fos Cavaou\t28.03%\t28.79%\t30.30%\t125\t124\t114\nDolphin Energy Ltd (Del) Abu Dhabi\t24.50%\t24.50%\t24.50%\t172\t118\t85\nQatar Liquefied Gas Company Limited II (Train B)\t16.70%\t16.70%\t16.70%\t184\t143\t82\nShtokman Development AG(a)\t25.00%\t25.00%\t25.00%\t214\t162\t35\nAMYRIS(b)\t22.03%\t0\t0\t101\t0\t0\nOther\t0\t0\t0\t749\t745\t700\nTotal associates\t\t\t\t4924\t4260\t3891\nOther\t0\t0\t0\t78\t0\t0\nTotal jointly-controlled entities\t\t\t\t78\t0\t0\nTotal Upstream\t\t\t\t5002\t4260\t3891\nCEPSA (Downstream share)\t48.83%\t48.83%\t48.83%\t2151\t1927\t1810\nSaudi Aramco Total Refining & Petrochemicals (Downstream share)(a)\t37.50%\t37.50%\t37.50%\t47\t60\t75\nWepec\t22.41%\t22.41%\t22.41%\t0\t0\t0\nOther\t0\t0\t0\t159\t123\t73\nTotal associates\t\t\t\t2357\t2110\t1958\nSARA(d)\t50.00%\t0\t0\t134\t0\t0\nTotalErg(b)\t49.00%\t0\t0\t289\t0\t0\nOther\t0\t0\t0\t2\t0\t0\nTotal jointly-controlled entities\t\t\t\t425\t0\t0\nTotal Downstream\t\t\t\t2782\t2110\t1958\nCEPSA (Chemicals share)\t48.83%\t48.83%\t48.83%\t411\t396\t424\nQatar Petrochemical Company Ltd.\t20.00%\t20.00%\t20.00%\t221\t205\t192\nSaudi Aramco Total Refining & Petrochemicals (Chemicals share)(a)\t37.50%\t37.50%\t37.50%\t4\t5\t6\nOther\t0\t0\t0\t68\t46\t55\nTotal associates\t\t\t\t704\t652\t677\nSamsung Total Petrochemicals(d)\t50.00%\t0\t0\t645\t0\t0\nTotal jointly-controlled entities\t\t\t\t645\t0\t0\nTotal Chemicals\t\t\t\t1349\t652\t677\nSanofi-Aventis(c)\t0\t7.39%\t11.38%\t0\t4235\t6137\nTotal associates\t\t\t\t0\t4235\t6137\nTotal jointly-controlled entities\t\t\t\t0\t0\t0\nTotal Corporate\t\t\t\t0\t4235\t6137\nTotal investments\t\t\t\t9133\t11257\t12663\nLoans\t\t\t\t2383\t2367\t2005\nTotal investments and loans\t\t\t\t11516\t13624\t14668\n", "q10k_tbl_177": "Equity in income (loss) (M€)\tAs of December 31\t\t\tFor the year ended December 31\t\t\n\t2010\t2009\t2008\t2010\t2009\t2008\n\t% owned\t\t\tequity in income (loss)\t\t\nNLNG\t15.00%\t15.00%\t15.00%\t207\t227\t554\nPetroCedeño - EM\t30.32%\t30.32%\t30.32%\t195\t166\t193\nCEPSA (Upstream share)\t48.83%\t48.83%\t48.83%\t57\t23\t50\nAngola LNG Ltd.\t13.60%\t13.60%\t13.60%\t8\t9\t10\nQatargas\t10.00%\t10.00%\t10.00%\t136\t114\t126\nSociété du Terminal Méthanier de Fos Cavaou\t28.03%\t28.79%\t30.30%\t0\t0\t(5)\nDolphin Energy Ltd (Del) Abu Dhabi\t24.50%\t24.50%\t24.50%\t121\t94\t83\nQatar Liquefied Gas Company Limited II (Train B)\t16.70%\t16.70%\t16.70%\t288\t8\t(11)\nShtokman Development AG(a)\t25.00%\t25.00%\t25.00%\t(5)\t4\t0\nAMYRIS(b)\t22.03%\t0\t0\t(3)\t\t\nOther\t0\t0\t0\t177\t214\t178\nTotal associates\t\t\t\t1181\t859\t1178\nOther\t0\t0\t0\t6\t0\t0\nTotal jointly-controlled entities\t\t\t\t6\t0\t0\nTotal Upstream\t\t\t\t1187\t859\t1178\nCEPSA (Downstream share)\t48.83%\t48.83%\t48.83%\t172\t149\t76\nSaudi Aramco Total Refining & Petrochemicals (Downstream share)(a)\t37.50%\t37.50%\t37.50%\t(19)\t(12)\t0\nWepec\t22.41%\t22.41%\t22.41%\t29\t0\t(110)\nOther\t0\t0\t0\t47\t81\t(13)\nTotal associates\t\t\t\t229\t218\t(47)\nSARA(d)\t50.00%\t0\t0\t31\t0\t0\nTotalErg(b)\t49.00%\t0\t0\t(11)\t0\t0\nOther\t0\t0\t0\t2\t0\t0\nTotal jointly-controlled entities\t\t\t\t22\t0\t0\nTotal Downstream\t\t\t\t251\t218\t(47)\nCEPSA (Chemicals share)\t48.83%\t48.83%\t48.83%\t78\t10\t10\nQatar Petrochemical Company Ltd.\t20.00%\t20.00%\t20.00%\t84\t74\t66\nSaudi Aramco Total Refining & Petrochemicals (Chemicals share)(a)\t37.50%\t37.50%\t37.50%\t(1)\t(1)\t0\nOther\t0\t0\t0\t41\t(4)\t(1)\nTotal associates\t\t\t\t202\t79\t75\nSamsung Total Petrochemicals(d)\t50.00%\t0\t0\t104\t0\t0\nTotal jointly-controlled entities\t\t\t\t104\t0\t0\nTotal Chemicals\t\t\t\t306\t79\t75\nSanofi-Aventis(c)\t0\t7.39%\t11.38%\t209\t486\t515\nTotal associates\t\t\t\t209\t486\t515\nTotal jointly-controlled entities\t\t\t\t0\t0\t0\nTotal Corporate\t\t\t\t209\t486\t515\nTotal investments\t\t\t\t1953\t1642\t1721\n", "q10k_tbl_178": "\t2010\t\t2009\t\t2008\t\n\t\tJointly-\t\tJointly-\t\tJointly-\n\t\tcontrolled\t\tcontrolled\t\tcontrolled\nAs of December 31 (M€)\tAssociates\tentities\tAssociates\tentities\tAssociates\tentities\nAssets\t19192\t2770\t22681\t0\t23173\t0\nShareholders' equity\t7985\t1148\t11257\t0\t12663\t0\nLiabilities\t11207\t1622\t11424\t0\t10510\t0\n", "q10k_tbl_179": "\t2010\t\t2009\t\t2008\t\n\t\tJointly-\t\tJointly-\t\tJointly-\n\t\tcontrolled\t\tcontrolled\t\tcontrolled\nFor the year ended December 31 (M€)\tAssociates\tentities\tAssociates\tentities\tAssociates\tentities\nRevenues from sales\t16529\t2575\t14434\t0\t19982\t0\nPre-tax income\t2389\t166\t2168\t0\t2412\t0\nIncome tax\t(568)\t(34)\t(526)\t0\t(691)\t0\nNet income\t1821\t132\t1642\t\t1721\t\n", "q10k_tbl_180": "\tCarrying\tUnrealized gain\tBalance\nAs of December 31 2010 (M€)\tamount\t(loss)\tsheet value\nSanofi-Aventis(a)\t3510\t(56)\t3454\nAreva(b)\t69\t63\t132\nArkema\t0\t0\t0\nChicago Mercantile Exchange Group(c)\t1\t9\t10\nOlympia Energy Fund - energy investment fund(d)\t37\t(3)\t34\nOther publicly traded equity securities\t2\t(1)\t1\nTotal publicly traded equity securities(e)\t3619\t12\t3631\nBBPP\t60\t0\t60\nBTC Limited\t141\t0\t141\nOther equity securities\t758\t0\t758\nTotal other equity securities(e)\t959\t0\t959\nOther investments\t4578\t12\t4590\n", "q10k_tbl_181": "\tCarrying\tUnrealized gain\tBalance\nAs of December 31 2009 (M€)\tamount\t(loss)\tsheet value\nAreva(b)\t69\t58\t127\nArkema\t15\t47\t62\nChicago Mercantile Exchange Group(c)\t1\t9\t10\nOlympia Energy Fund - energy investment fund(d)\t35\t(2)\t33\nOther publicly traded equity securities\t0\t0\t0\nTotal publicly traded equity securities(e)\t120\t112\t232\nBBPP\t72\t0\t72\nBTC Limited\t144\t0\t144\nOther equity securities\t714\t0\t714\nTotal other equity securities(e)\t930\t0\t930\nOther investments\t1050\t112\t1162\n\tCarrying\tUnrealized gain\tBalance\nAs of December 31 2008 (M€)\tamount\t(loss)\tsheet value\nAreva(b)\t69\t59\t128\nArkema\t16\t15\t31\nChicago Mercantile Exchange Group(c)\t1\t5\t6\nOlympia Energy Fund - energy investment fund(d)\t36\t(5)\t31\nOther publicly traded equity securities\t0\t0\t0\nTotal publicly traded equity securities(e)\t122\t74\t196\nBBPP\t75\t0\t75\nBTC Limited\t161\t0\t161\nOther equity securities\t733\t0\t733\nTotal other equity securities(e)\t969\t0\t969\nOther investments\t1091\t74\t1165\n", "q10k_tbl_182": "(b)\tUnrealized gain based on the investment certificate.\n(c)\tThe Nymex Holdings Inc. securities have been traded during the acquisition process running from June 11 to August 22 2008 through which Chicago Mercantile Exchange Group acquired all the Nymex Holdings Inc. securities.\n(d)\tSecurities acquired in 2008.\n(e)\tIncluding cumulative impairments of €597 million in 2010 €599 million in 2009 and €608 million in 2008.\n", "q10k_tbl_183": "\tGross\tValuation\tNet\nAs of December 31 2010 (M€)\tvalue\tallowance\tvalue\nDeferred income tax assets\t1378\t0\t1378\nLoans and advances(a)\t2060\t(464)\t1596\nOther\t681\t0\t681\nTotal\t4119\t(464)\t3655\n", "q10k_tbl_184": "\tGross\tValuation\tNet\nAs of December 31 2009 (M€)\tvalue\tallowance\tvalue\nDeferred income tax assets\t1164\t0\t1164\nLoans and advances(a)\t1871\t(587)\t1284\nOther\t633\t0\t633\nTotal\t3668\t(587)\t3081\n", "q10k_tbl_185": "\tGross\tValuation\tNet\nAs of December 31 2008 (M€)\tvalue\tallowance\tvalue\nDeferred income tax assets\t1010\t0\t1010\nLoans and advances(a)\t1932\t(529)\t1403\nOther\t631\t0\t631\nTotal\t3573\t(529)\t3044\n", "q10k_tbl_186": "\t\t\t\tCurrency\t\n\tValuation\t\t\ttranslation\tValuation\n\tallowance as of\t\t\tadjustment and\tallowance as of\nFor the Year Ended December 31 (M€)\tJanuary 1\tIncreases\tDecreases\tother variations\tDecember 31\n2010\t(587)\t(33)\t220\t(64)\t(464)\n2009\t(529)\t(19)\t29\t(68)\t(587)\n2008\t(527)\t(33)\t52\t(21)\t(529)\n", "q10k_tbl_187": "\tGross\tValuation\tNet\nAs of December 31 2010 (M€)\tvalue\tallowance\tvalue\nCrude oil and natural gas\t4990\t0\t4990\nRefined products\t7794\t(28)\t7766\nChemicals products\t1350\t(99)\t1251\nOther inventories\t1911\t(318)\t1593\nTotal\t16045\t(445)\t15600\n", "q10k_tbl_188": "\tGross\tValuation\tNet\nAs of December 31 2009 (M€)\tvalue\tallowance\tvalue\nCrude oil and natural gas\t4581\t0\t4581\nRefined products\t6647\t(18)\t6629\nChemicals products\t1234\t(113)\t1121\nOther inventories\t1822\t(286)\t1536\nTotal\t14284\t(417)\t13867\n", "q10k_tbl_189": "\tGross\tValuation\tNet\nAs of December 31 2008 (M€)\tvalue\tallowance\tvalue\nCrude oil and natural gas\t2772\t(326)\t2446\nRefined products\t4954\t(416)\t4538\nChemicals products\t1419\t(105)\t1314\nOther inventories\t1591\t(268)\t1323\nTotal\t10736\t(1115)\t9621\n", "q10k_tbl_190": "\t\t\tCurrency\t\n\t\t\ttranslation\tValuation\n\tValuation\t\tadjustment\tallowance\n\tallowance as of\tIncrease\tand other\tas of\nFor the year ended December 31 (M€)\tJanuary 1\t(net)\tvariations\tDecember 31\n2010\t(417)\t(39)\t11\t(445)\n2009\t(1115)\t700\t(2)\t(417)\n2008\t(325)\t(740)\t(50)\t(1115)\n", "q10k_tbl_191": "\tGross\tValuation\tNet\nAs of December 31 2010 (M€)\tvalue\tallowance\tvalue\nAccounts receivable\t18635\t(476)\t18159\nRecoverable taxes\t2227\t0\t2227\nOther operating receivables\t4543\t(136)\t4407\nDeferred income tax\t151\t0\t151\nPrepaid expenses\t657\t0\t657\nOther current assets\t41\t0\t41\nOther current assets\t7619\t(136)\t7483\n", "q10k_tbl_192": "\tGross\tValuation\tNet\nAs of December 31 2009 (M€)\tvalue\tallowance\tvalue\nAccounts receivable\t16187\t(468)\t15719\nRecoverable taxes\t2156\t0\t2156\nOther operating receivables\t5214\t(69)\t5145\nDeferred income tax\t214\t0\t214\nPrepaid expenses\t638\t0\t638\nOther current assets\t45\t0\t45\nOther current assets\t8267\t(69)\t8198\n", "q10k_tbl_193": "\tGross\tValuation\tNet\nAs of December 31 2008 (M€)\tvalue\tallowance\tvalue\nAccounts receivable\t15747\t(460)\t15287\nRecoverable taxes\t2510\t0\t2510\nOther operating receivables\t6227\t(19)\t6208\nDeferred income tax\t206\t0\t206\nPrepaid expenses\t650\t0\t650\nOther current assets\t68\t0\t68\nOther current assets\t9661\t(19)\t9642\n", "q10k_tbl_194": "\tValuation\t\tCurrency translation\tValuation\n\tallowance as of\t\tadjustments and\tallowance as of\n(M€)\tJanuary 1\tIncrease (net)\tother variations\tDecember 31\nAccounts receivable\t\t\t\t\n2010\t(468)\t(31)\t23\t(476)\n2009\t(460)\t(17)\t9\t(468)\n2008\t(482)\t9\t13\t(460)\nOther current assets\t\t\t\t\n2010\t(69)\t(66)\t(1)\t(136)\n2009\t(19)\t(14)\t(36)\t(69)\n2008\t(27)\t7\t1\t(19)\n", "q10k_tbl_195": "As of January 1 2008\t\t2395532097\nShares issued in connection with:\tCapital increase reserved for employees\t4870386\n\tExercise of TOTAL share subscription options\t1178167\n\tExchange guarantee offered to the beneficiaries of Elf Aquitaine share subscription options\t227424\nCancellation of shares(a)\t\t(30000000)\nAs of January 1 2009\t\t2371808074\nShares issued in connection with:\tExercise of TOTAL share subscription options\t934780\n\tExchange guarantee offered to the beneficiaries of Elf Aquitaine share subscription options\t480030\nCancellation of shares(b)\t\t(24800000)\nAs of January 1 2010\t\t2348422884\nShares issued in connection with:\tExercise of TOTAL share subscription options\t1218047\nAs of December 31 2010(c)\t\t2349640931\n", "q10k_tbl_196": "(a)\tDecided by the Board of Directors on July 31 2008.\n(b)\tDecided by the Board of Directors on July 30 2009.\n(c)\tIncluding 112487679 treasury shares deducted from consolidated shareholders' equity.\n", "q10k_tbl_197": "\t2010\t2009\t2008\nNumber of shares as of January 1\t2348422884\t2371808074\t2395532097\nNumber of shares issued during the year (pro rated)\t\t\t\nExercise of TOTAL share subscription options\t412114\t221393\t742588\nExercise of TOTAL share purchase options\t984800\t93827\t2426827\nExchange guarantee offered to the beneficiaries of Elf Aquitaine share subscription options\t0\t393623\t86162\nTOTAL restricted shares\t416420\t1164389\t1112393\nGlobal free TOTAL share plan(a)\t15\t0\t0\nCapital increase reserved for employees\t0\t0\t3246924\nTOTAL shares held by TOTAL S.A. or by its subsidiaries and deducted from shareholders' equity\t(115407190)\t(143082095)\t(168290440)\nWeighted-average number of shares\t2234829043\t2230599211\t2234856551\nDilutive effect\t\t\t\nTOTAL share subscription and purchase options\t1758006\t1711961\t6784200\nTOTAL restricted shares\t6031963\t4920599\t4172944\nGlobal free TOTAL share plan(a)\t1504071\t0\t0\nExchange guarantee offered to the beneficiaries of Elf Aquitaine share subscription options\t0\t60428\t460935\nCapital increase reserved for employees\t371493\t0\t383912\nWeighted-average number of diluted shares\t2244494576\t2237292199\t2246658542\n", "q10k_tbl_198": "0\t6017499 shares allocated to covering TOTAL share purchase option plans for Group employees and executive officers;\n0\t5799400 shares allocated to TOTAL restricted shares plans for Group employees; and\n0\t3259023 shares intended to be allocated to new TOTAL share purchase option plans or to new restricted shares plans.\n", "q10k_tbl_199": "0\t12627522 shares allocated to covering TOTAL share purchase option plans for Group employees;\n0\t5323305 shares allocated to TOTAL restricted shares plans for Group employees; and\n0\t24800000 shares purchased for cancellation between January and October 2008 pursuant to the authorization granted by the shareholders' meetings held on May 11 2007 and May 16 2008. The Board of Directors on July 30 2009 decided to cancel these 24800000 shares acquired at an average price of €49.28 per share.\n", "q10k_tbl_200": "0\t2023672 shares held by a consolidated subsidiary Total Nucléaire 100% indirectly controlled by TOTAL S.A.; and\n0\t98307596 shares held by subsidiaries of Elf Aquitaine (Financière Valorgest Sogapar and Fingestval).\n", "q10k_tbl_201": "For the year ended December 31 (M€)\t2010\t\t2009\t\t2008\t\nCurrency translation adjustment\t\t2231\t\t(244)\t\t(722)\n- Unrealized gain/(loss) of the period\t2234\t\t(243)\t\t(722)\t\n- Less gain/(loss) included in net income\t3\t\t1\t\t0\t\nAvailable for sale financial assets\t\t(100)\t\t38\t\t(254)\n- Unrealized gain/(loss) of the period\t(50)\t\t38\t\t(254)\t\n- Less gain/(loss) included in net income\t50\t\t0\t\t0\t\nCash flow hedge\t\t(80)\t\t128\t\t0\n- Unrealized gain/(loss) of the period\t(195)\t\t349\t\t0\t\n- Less gain/(loss) included in net income\t(115)\t\t221\t\t0\t\nShare of other comprehensive income of equity affiliates net amount\t\t302\t\t234\t\t173\nOther\t\t(7)\t\t(5)\t\t1\n- Unrealized gain/(loss) of the period\t(7)\t\t(5)\t\t1\t\n- Less gain/(loss) included in net income\t0\t\t0\t\t0\t\nTax effect\t\t28\t\t(38)\t\t30\nTotal other comprehensive income net amount\t\t2374\t\t113\t\t(772)\n", "q10k_tbl_202": "\t2010\t\t\t2009\t\t\t2008\t\t\n\tPre-tax\tTax\tNet\tPre-tax\tTax\tNet\tPre-tax\tTax\tNet\nFor the year ended December 31 (M€)\tamount\teffect\tamount\tamount\teffect\tamount\tamount\teffect\tamount\nCurrency translation adjustment\t2231\t0\t2231\t(244)\t0\t(244)\t(722)\t0\t(722)\nAvailable for sale financial assets\t(100)\t2\t(98)\t38\t4\t42\t(254)\t30\t(224)\nCash flow hedge\t(80)\t26\t(54)\t128\t(42)\t86\t0\t0\t0\nShare of other comprehensive income of equity affiliates net amount\t302\t0\t302\t234\t0\t234\t173\t0\t173\nOther\t(7)\t0\t(7)\t(5)\t0\t(5)\t1\t0\t1\nTotal other comprehensive income\t2346\t28\t2374\t151\t(38)\t113\t(802)\t30\t(772)\n", "q10k_tbl_203": "As of December 31 (M€)\t2010\t2009\t2008\nPension benefits liabilities\t1268\t1236\t1187\nOther benefits liabilities\t605\t592\t608\nRestructuring reserves (early retirement plans)\t298\t212\t216\nTotal\t2171\t2040\t2011\n", "q10k_tbl_204": "\tPension benefits\t\t\tOther benefits\t\t\nAs of December 31 (M€)\t2010\t2009\t2008\t2010\t2009\t2008\nChange in benefit obligation\t\t\t\t\t\t\nBenefit obligation at beginning of year\t8169\t7405\t8129\t547\t544\t583\nService cost\t159\t134\t143\t11\t10\t14\nInterest cost\t441\t428\t416\t29\t30\t24\nCurtailments\t(4)\t(5)\t(3)\t(3)\t(1)\t0\nSettlements\t(60)\t(3)\t(5)\t0\t0\t(4)\nSpecial termination benefits\t0\t0\t0\t1\t0\t0\nPlan participants' contributions\t11\t10\t12\t0\t0\t0\nBenefits paid\t(471)\t(484)\t(463)\t(33)\t(33)\t(37)\nPlan amendments\t28\t118\t12\t1\t(2)\t(12)\nActuarial losses (gains)\t330\t446\t(248)\t57\t0\t(27)\nForeign currency translation and other\t137\t120\t(588)\t13\t(1)\t3\nBenefit obligation at year-end\t8740\t8169\t7405\t623\t547\t544\nChange in fair value of plan assets\t\t\t\t\t\t\nFair value of plan assets at beginning of year\t(6286)\t(5764)\t(6604)\t0\t0\t0\nExpected return on plan assets\t(396)\t(343)\t(402)\t0\t0\t0\nActuarial losses (gains)\t(163)\t(317)\t1099\t0\t0\t0\nSettlements\t56\t2\t2\t0\t0\t0\nPlan participants' contributions\t(11)\t(10)\t(12)\t0\t0\t0\nEmployer contributions(a)\t(269)\t(126)\t(855)\t0\t0\t0\nBenefits paid\t394\t396\t375\t0\t0\t0\nForeign currency translation and other\t(134)\t(124)\t633\t0\t0\t0\nFair value of plan assets at year-end\t(6809)\t(6286)\t(5764)\t0\t0\t0\nUnfunded status\t1931\t1883\t1641\t623\t547\t544\nUnrecognized prior service cost\t(105)\t(153)\t(48)\t10\t15\t21\nUnrecognized actuarial (losses) gains\t(1170)\t(1045)\t(953)\t(28)\t30\t43\nAsset ceiling\t9\t9\t5\t0\t0\t0\nNet recognized amount\t665\t694\t645\t605\t592\t608\nPension benefits and other benefits liabilities\t1268\t1236\t1187\t605\t592\t608\nOther non-current assets\t(603)\t(542)\t(542)\t0\t0\t0\n", "q10k_tbl_205": "For the year ended December 31 (M€)\t2010\t2009\t2008\t2007\nExperience actuarial (gains) losses related to the defined benefit obligation\t(54)\t(108)\t12\t80\nExperience actuarial (gains) losses related to the fair value of plan assets\t(163)\t(317)\t1099\t140\n", "q10k_tbl_206": "As of December 31 (M€)\t2010\t2009\t2008\t2007\t2006\nPension benefits\t\t\t\t\t\nBenefit obligation\t8740\t8169\t7405\t8129\t8742\nFair value of plan assets\t(6809)\t(6286)\t(5764)\t(6604)\t(6401)\nUnfunded status\t1931\t1883\t1641\t1525\t2341\nOther benefits\t\t\t\t\t\nBenefits obligation\t623\t547\t544\t583\t648\nFair value of plan assets\t0\t0\t0\t0\t0\nUnfunded status\t623\t547\t544\t583\t648\n", "q10k_tbl_207": "Estimated future payments (M€)\tPension benefits\tOther benefits\n2011\t487\t38\n2012\t478\t38\n2013\t477\t38\n2014\t477\t39\n2015\t497\t40\n2016-2020\t2628\t203\n", "q10k_tbl_208": "Asset allocation\tPension benefits\t\t\nAs of December 31\t2010\t2009\t2008\nEquity securities\t34%\t31%\t25%\nDebt securities\t60%\t62%\t56%\nMonetary\t3%\t3%\t16%\nReal estate\t3%\t4%\t3%\n", "q10k_tbl_209": "Assumptions used to determine benefits obligations\tPension benefits\t\t\tOther benefits\t\t\nAs of December 31\t2010\t2009\t2008\t2010\t2009\t2008\nDiscount rate (weighted average for all regions)\t5.01%\t5.41%\t5.93%\t5.00%\t5.60%\t6.00%\nOf which Euro zone\t4.58%\t5.12%\t5.72%\t4.55%\t5.18%\t5.74%\nOf which United States\t5.49%\t6.00%\t6.23%\t5.42%\t5.99%\t6.21%\nOf which United Kingdom\t5.50%\t5.50%\t6.00%\t0\t0\t6.00%\nAverage expected rate of salary increase\t4.55%\t4.50%\t4.56%\t0\t0\t0\nExpected rate of healthcare inflation\t\t\t\t\t\t\n- Initial rate\t0\t0\t0\t4.82%\t4.91%\t4.88%\n- Ultimate rate\t0\t0\t0\t3.75%\t3.79%\t3.64%\n", "q10k_tbl_210": "Assumptions used to determine the net periodic benefit cost (income)\tPension benefits\t\t\tOther benefits\t\t\nFor the year ended December 31\t2010\t2009\t2008\t2010\t2009\t2008\nDiscount rate (weighted average for all regions)\t5.41%\t5.93%\t5.50%\t5.60%\t6.00%\t5.50%\nOf which Euro zone\t5.12%\t5.72%\t5.15%\t5.18%\t5.74%\t5.14%\nOf which United States\t6.00%\t6.23%\t6.00%\t5.99%\t6.21%\t5.98%\nOf which United Kingdom\t5.50%\t6.00%\t5.75%\t0\t6.00%\t5.75%\nAverage expected rate of salary increase\t4.50%\t4.56%\t4.29%\t0\t0\t0\nExpected return on plan assets\t6.39%\t6.14%\t6.60%\t0\t0\t0\nExpected rate of healthcare inflation\t\t\t\t\t\t\n- Initial rate\t0\t0\t0\t4.91%\t4.88%\t5.16%\n- Ultimate rate\t0\t0\t0\t3.79%\t3.64%\t3.64%\n", "q10k_tbl_211": "\t0.5%\t0.5%\n(M€)\tincrease\tdecrease\nBenefit obligation as of December 31 2010\t(520)\t574\n2011 net periodic benefit cost (income)\t(19)\t52\n", "q10k_tbl_212": "\tPension benefits\t\t\t\t\t\n\t\t\t\tOther benefits\t\t\nFor the year ended December 31 (M€)\t2010\t2009\t2008\t2010\t2009\t2008\nService cost\t159\t134\t143\t11\t10\t14\nInterest cost\t441\t428\t416\t29\t30\t24\nExpected return on plan assets\t(396)\t(343)\t(402)\t0\t0\t0\nAmortization of prior service cost\t74\t13\t34\t(5)\t(7)\t(10)\nAmortization of actuarial losses (gains)\t66\t50\t22\t(4)\t(6)\t(2)\nAsset ceiling\t(3)\t4\t1\t0\t0\t0\nCurtailments\t(3)\t(4)\t(3)\t(3)\t(1)\t0\nSettlements\t7\t(1)\t(2)\t0\t0\t(3)\nSpecial termination benefits\t0\t0\t0\t1\t0\t0\nNet periodic benefit cost (income)\t345\t281\t209\t29\t26\t23\n", "q10k_tbl_213": "\t1% point\t1% point\n(M€)\tincrease\tdecrease\nBenefit obligation as of December 31 2010\t63\t(52)\n2010 net periodic benefit cost (income)\t5\t(4)\n", "q10k_tbl_214": "As of December 31 (M€)\t2010\t2009\t2008\nLitigations and accrued penalty claims\t485\t423\t546\nProvisions for environmental contingencies\t644\t623\t558\nAsset retirement obligations\t5917\t5469\t4500\nOther non-current provisions\t1116\t1331\t1804\nOther non-current liabilities\t936\t1535\t450\nTotal\t9098\t9381\t7858\n", "q10k_tbl_215": "0\tThe contingency reserve related to the Toulouse-AZF plant explosion (civil liability) for €31 million as of December 31 2010;\n0\tProvisions related to restructuring activities in the Downstream and Chemicals segments for €261 million as of December 31 2010; and\n0\tThe contingency reserve related to the Buncefield depot explosion (civil liability) for €194 million as of December 31 2010.\n", "q10k_tbl_216": "0\tThe contingency reserve related to the Toulouse-AZF plant explosion (civil liability) for €40 million as of December 31 2009;\n0\tProvisions related to restructuring activities in the Downstream and Chemicals segments for €130 million as of December 31 2009; and\n0\tThe contingency reserve related to the Buncefield depot explosion (civil liability) for €295 million as of December 31 2009.\n", "q10k_tbl_217": "\t\t\t\tCurrency\t\t\n\t\t\t\ttranslation\t\tAs of\n(M€)\tAs of January 1\tAllowances\tReversals\tadjustment\tOther\tDecember 31\n2010\t9381\t1052\t(971)\t497\t(861)\t9098\n2009\t7858\t1254\t(1413)\t202\t1480\t9381\n2008\t6843\t1424\t(864)\t(460)\t915\t7858\n", "q10k_tbl_218": "0\tAsset retirement obligations for €338 million (accretion);\n0\tEnvironmental contingencies for €88 million in the Downstream and Chemicals segments;\n0\tThe contingency reserve related to the Buncefield depot explosion (civil liability) for €79 million; and\n0\tProvisions related to restructuring of activities for €226 million.\n", "q10k_tbl_219": "0\tAsset retirement obligations for €283 million (accretion);\n0\tEnvironmental contingencies for €147 million in the Downstream and Chemicals segments;\n0\tThe contingency reserve related to the Buncefield depot explosion (civil liability) for €223 million; and\n0\tProvisions related to restructuring of activities for €121 million.\n", "q10k_tbl_220": "0\tAsset retirement obligations for €229 million (accretion);\n0\tThe contingency reserve related to the Toulouse-AZF plant explosion (civil liability) for €140 million;\n0\tEnvironmental contingencies for €89 million;\n0\tAn allowance of €48 million for litigation reserves in connection with antitrust investigations as described in Note 32 to the Consolidated Financial Statements \"Other risks and contingent liabilities\"; and\n0\tProvisions related to restructuring of activities for €27 million.\n", "q10k_tbl_221": "0\tProvisions for asset retirement obligations for €214 million;\n0\t€26 million for litigation reserves in connection with antitrust investigations;\n0\tEnvironmental contingencies written back for €66 million;\n0\tThe contingency reserve related to the Toulouse-AZF plant explosion (civil liability) written back for €9 million;\n0\tThe contingency reserve related to the Buncefield depot explosion (civil liability) written back for €190 million; and\n0\tProvisions for restructuring and social plans written back for €60 million.\n", "q10k_tbl_222": "0\tProvisions for asset retirement obligations for €191 million;\n0\t€52 million for litigation reserves in connection with antitrust investigations;\n0\tEnvironmental contingencies written back for €86 million;\n0\tThe contingency reserve related to the Toulouse-AZF plant explosion (civil liability) written back for €216 million;\n0\tThe contingency reserve related to the Buncefield depot explosion (civil liability) written back for €375 million; and\n0\tProvisions for restructuring and social plans written back for €28 million.\n", "q10k_tbl_223": "0\tProvisions for asset retirement obligations for €280 million;\n0\t€163 million for litigation reserves in connection with antitrust investigations;\n0\tEnvironmental contingencies written back for €96 million;\n0\tThe contingency reserve related to the Toulouse-AZF plant explosion (civil liability) written back for €18 million; and\n0\tProvisions for restructuring and social plans written back for €10 million.\n", "q10k_tbl_224": "\t\t\tRevision\t\tSpending on\tCurrency\t\t\n\tAs of\t\tin\tNew\texisting\ttranslation\t\tAs of\n(M€)\tJanuary 1\tAccretion\testimates\tobligations\tobligations\tadjustment\tOther\tDecember 31\n2010\t5469\t338\t79\t175\t(214)\t316\t(246)\t5917\n2009\t4500\t283\t447\t179\t(191)\t232\t19\t5469\n2008\t4206\t229\t563\t188\t(280)\t(414)\t8\t4500\n", "q10k_tbl_225": "As of December 31 2010 (M€)\t\t\t\n(Assets)/Liabilities\tSecured\tUnsecured\tTotal\nNon-current financial debt\t287\t20496\t20783\nof which hedging instruments of non-current financial debt (liabilities)\t0\t178\t178\nHedging instruments of non-current financial debt (assets)(a)\t0\t(1870)\t(1870)\nNon-current financial debt - net of hedging instruments\t287\t18626\t18913\nBonds after fair value hedge\t0\t15491\t15491\nFixed rate bonds and bonds after cash flow hedge\t0\t2836\t2836\nBank and other floating rate\t47\t189\t236\nBank and other fixed rate\t65\t110\t175\nFinancial lease obligations\t175\t0\t175\nNon-current financial debt - net of hedging instruments\t287\t18626\t18913\n", "q10k_tbl_226": "As of December 31 2009 (M€)\t\t\t\n(Assets)/Liabilities\tSecured\tUnsecured\tTotal\nNon-current financial debt\t312\t19125\t19437\nof which hedging instruments of non-current financial debt (liabilities)\t0\t241\t241\nHedging instruments of non-current financial debt (assets)(a)\t0\t(1025)\t(1025)\nNon-current financial debt - net of hedging instruments\t312\t18100\t18412\nBonds after fair value hedge\t0\t15884\t15884\nFixed rate bonds and bonds after cash flow hedge\t0\t1700\t1700\nBank and other floating rate\t60\t379\t439\nBank and other fixed rate\t50\t79\t129\nFinancial lease obligations\t202\t58\t260\nNon-current financial debt - net of hedging instruments\t312\t18100\t18412\n", "q10k_tbl_227": "As of December 31 2008 (M€)\t\t\t\n(Assets)/Liabilities\tSecured\tUnsecured\tTotal\nNon-current financial debt\t895\t15296\t16191\nof which hedging instruments of non-current financial debt (liabilities)\t0\t440\t440\nHedging instruments of non-current financial debt (assets)(a)\t0\t(892)\t(892)\nNon-current financial debt - net of hedging instruments\t895\t14404\t15299\nBonds after fair value hedge\t0\t13380\t13380\nFixed rate bonds and bonds after cash flow hedge\t0\t287\t287\nBank and other floating rate\t553\t665\t1218\nBank and other fixed rate\t140\t6\t146\nFinancial lease obligations\t202\t66\t268\nNon-current financial debt - net of hedging instruments\t895\t14404\t15299\n", "q10k_tbl_228": "\t\tFair value after hedging as of\t\t\t\t\t\n\tYear of\tDecember 31\tDecember 31\tDecember 31\t\t\tInitial rate before hedging\nBonds after fair value hedge (M€)\tissue\t2010\t2009\t2008\tCurrency\tMaturity\tinstruments\nParent company\t\t\t\t\t\t\t\nBond\t1997\t- -\t0\t124\tFRF\t2009\t6.200%\nBond\t1998\t0\t0\t119\tFRF\t2009\t5.125%\nBond\t1998\t125\t116\t121\tFRF\t2013\t5.000%\nBond\t2000\t0\t61\t63\tEUR\t2010\t5.650%\nCurrent portion (less than one year)\t\t0\t(61)\t(243)\t\t\t\nTotal parent company\t\t125\t116\t184\t\t\t\nElf Aquitaine SA\t\t\t\t\t\t\t\nBond\t1999\t0\t0\t1 003\tEUR\t2009\t4.500%\nCurrent portion (less than one year)\t\t0\t0\t(1 003)\t\t\t\nTotal Elf Aquitaine SA\t\t0\t0\t0\t\t\t\nTOTAL CAPITAL(a)\t\t\t\t\t\t\t\nBond\t2002\t15\t14\t14\tUSD\t2012\t5.890%\nBond\t2003\t0\t0\t52\tAUD\t2009\t6.250%\nBond\t2003\t0\t0\t154\tCHF\t2009\t2.385%\nBond\t2003\t0\t160\t166\tCHF\t2010\t2.385%\nBond\t2003\t22\t21\t22\tUSD\t2013\t4.500%\nBond\t2003-2004\t0\t0\t395\tUSD\t2009\t3.500%\nBond\t2004\t0\t0\t57\tAUD\t2009\t6.000%\nBond\t2004\t0\t0\t28\tAUD\t2009\t6.000%\nBond\t2004\t0\t53\t55\tCAD\t2010\t4.000%\nBond\t2004\t0\t113\t117\tCHF\t2010\t2.385%\nBond\t2004\t0\t438\t454\tEUR\t2010\t3.750%\nBond\t2004\t0\t322\t334\tGBP\t2010\t4.875%\nBond\t2004\t0\t128\t132\tGBP\t2010\t4.875%\nBond\t2004\t0\t185\t191\tGBP\t2010\t4.875%\nBond\t2004\t57\t53\t55\tAUD\t2011\t5.750%\nBond\t2004\t116\t107\t111\tCAD\t2011\t4.875%\nBond\t2004\t235\t203\t216\tUSD\t2011\t4.125%\nBond\t2004\t75\t69\t72\tUSD\t2011\t4.125%\nBond\t2004\t125\t116\t120\tCHF\t2012\t2.375%\nBond\t2004\t51\t47\t49\tNZD\t2014\t6.750%\nBond\t2005\t0\t0\t36\tUSD\t2009\t3.500%\nBond\t2005\t57\t53\t55\tAUD\t2011\t5.750%\nBond\t2005\t60\t56\t58\tCAD\t2011\t4.000%\nBond\t2005\t120\t112\t116\tCHF\t2011\t1.625%\nBond\t2005\t226\t226\t226\tCHF\t2011\t1.625%\nBond\t2005\t139\t144\t144\tUSD\t2011\t4.125%\nBond\t2005\t63\t63\t63\tAUD\t2012\t5.750%\nBond\t2005\t194\t180\t187\tCHF\t2012\t2.135%\nBond\t2005\t65\t65\t65\tCHF\t2012\t2.135%\nBond\t2005\t97\t97\t98\tCHF\t2012\t2.375%\nBond\t2005\t391\t363\t376\tEUR\t2012\t3.250%\nBond\t2005\t57\t57\t57\tNZD\t2012\t6.500%\nBond\t2006\t0\t75\t75\tGBP\t2010\t4.875%\nBond\t2006\t0\t50\t50\tEUR\t2010\t3.750%\nBond\t2006\t0\t50\t50\tEUR\t2010\t3.750%\nBond\t2006\t0\t100\t102\tEUR\t2010\t3.750%\nBond\t2006\t42\t42\t42\tEUR\t2011\tEURIBOR 3 months +0.040%\nBond\t2006\t300\t300\t300\tEUR\t2011\t3.875%\nBond\t2006\t150\t150\t150\tEUR\t2011\t3.875%\nBond\t2006\t300\t300\t300\tEUR\t2011\t3.875%\nBond\t2006\t120\t120\t120\tUSD\t2011\t5.000%\nBond\t2006\t300\t300\t300\tEUR\t2011\t3.875%\nBond\t2006\t472\t472\t473\tUSD\t2011\t5.000%\n", "q10k_tbl_229": "\t\tFair value after hedging as of\t\t\t\t\t\n\tYear of\tDecember 31\tDecember 31\tDecember 31\t\t\tInitial rate before hedging\nBonds after fair value hedge (M€)\tissue\t2010\t2009\t2008\tCurrency\tMaturity\tinstruments\nBond\t2006\t62\t62\t62\tAUD\t2012\t5.625%\nBond\t2006\t72\t72\t72\tCAD\t2012\t4.125%\nBond\t2006\t100\t100\t100\tEUR\t2012\t3.250%\nBond\t2006\t74\t74\t74\tGBP\t2012\t4.625%\nBond\t2006\t100\t100\t100\tEUR\t2012\t3.250%\nBond\t2006\t125\t125\t125\tCHF\t2013\t2.510%\nBond\t2006\t127\t127\t127\tCHF\t2014\t2.635%\nBond\t2006\t130\t130\t130\tCHF\t2016\t2.385%\nBond\t2006\t65\t65\t65\tCHF\t2016\t2.385%\nBond\t2006\t64\t64\t64\tCHF\t2016\t2.385%\nBond\t2006\t63\t63\t64\tCHF\t2016\t2.385%\nBond\t2006\t129\t129\t129\tCHF\t2018\t3.135%\nBond\t2007\t0\t60\t60\tCHF\t2010\t2.385%\nBond\t2007\t0\t74\t74\tGBP\t2010\t4.875%\nBond\t2007\t77\t77\t77\tUSD\t2011\t5.000%\nBond\t2007\t370\t370\t370\tUSD\t2012\t5.000%\nBond\t2007\t222\t222\t222\tUSD\t2012\t5.000%\nBond\t2007\t61\t61\t61\tAUD\t2012\t6.500%\nBond\t2007\t72\t72\t72\tCAD\t2012\t4.125%\nBond\t2007\t71\t71\t71\tGBP\t2012\t4.625%\nBond\t2007\t300\t300\t300\tEUR\t2013\t4.125%\nBond\t2007\t73\t73\t74\tGBP\t2013\t5.500%\nBond\t2007\t306\t306\t306\tGBP\t2013\t5.500%\nBond\t2007\t72\t72\t73\tGBP\t2013\t5.500%\nBond\t2007\t248\t248\t248\tCHF\t2014\t2.635%\nBond\t2007\t31\t31\t31\tJPY\t2014\t1.505%\nBond\t2007\t61\t61\t61\tCHF\t2014\t2.635%\nBond\t2007\t49\t49\t49\tJPY\t2014\t1.723%\nBond\t2007\t121\t121\t121\tCHF\t2015\t3.125%\nBond\t2007\t300\t300\t300\tEUR\t2017\t4.700%\nBond\t2007\t76\t76\t76\tCHF\t2018\t3.135%\nBond\t2007\t60\t60\t60\tCHF\t2018\t3.135%\nBond\t2008\t0\t63\t63\tGBP\t2010\t4.875%\nBond\t2008\t0\t66\t66\tGBP\t2010\t4.875%\nBond\t2008\t92\t92\t92\tAUD\t2011\t7.500%\nBond\t2008\t100\t100\t100\tEUR\t2011\t3.875%\nBond\t2008\t150\t150\t151\tEUR\t2011\t3.875%\nBond\t2008\t50\t50\t50\tEUR\t2011\t3.875%\nBond\t2008\t50\t50\t50\tEUR\t2011\t3.875%\nBond\t2008\t60\t60\t60\tJPY\t2011\tEURIBOR 6 months + 0.018%\nBond\t2008\t102\t102\t102\tUSD\t2011\t3.750%\nBond\t2008\t62\t62\t62\tCHF\t2012\t2.135%\nBond\t2008\t124\t124\t124\tCHF\t2012\t3.635%\nBond\t2008\t46\t46\t46\tCHF\t2012\t2.385%\nBond\t2008\t92\t92\t92\tCHF\t2012\t2.385%\nBond\t2008\t64\t64\t64\tCHF\t2012\t2.385%\nBond\t2008\t50\t50\t50\tEUR\t2012\t3.250%\nBond\t2008\t63\t63\t63\tGBP\t2012\t4.625%\nBond\t2008\t63\t63\t63\tGBP\t2012\t4.625%\nBond\t2008\t63\t63\t64\tGBP\t2012\t4.625%\nBond\t2008\t62\t62\t62\tNOK\t2012\t6.000%\nBond\t2008\t69\t69\t69\tUSD\t2012\t5.000%\nBond\t2008\t60\t60\t60\tAUD\t2013\t7.500%\nBond\t2008\t61\t61\t61\tAUD\t2013\t7.500%\nBond\t2008\t127\t127\t128\tCHF\t2013\t3.135%\nBond\t2008\t62\t62\t63\tCHF\t2013\t3.135%\nBond\t2008\t200\t200\t200\tEUR\t2013\t4.125%\nBond\t2008\t100\t100\t100\tEUR\t2013\t4.125%\nBond\t2008\t1000\t1000\t1002\tEUR\t2013\t4.750%\nBond\t2008\t63\t63\t63\tGBP\t2013\t5.500%\n", "q10k_tbl_230": "\t\tFair value after hedging as of\t\t\t\t\t\n\tYear of\tDecember 31\tDecember 31\tDecember 31\t\t\tInitial rate before hedging\nBonds after fair value hedge (M€)\tissue\t2010\t2009\t2008\tCurrency\tMaturity\tinstruments\nBond\t2008\t149\t149\t149\tJPY\t2013\tEURIBOR 6 months + 0.008%\nBond\t2008\t191\t191\t194\tUSD\t2013\t4.000%\nBond\t2008\t61\t61\t61\tCHF\t2015\t3.135%\nBond\t2008\t62\t62\t62\tCHF\t2015\t3.135%\nBond\t2008\t61\t61\t62\tCHF\t2015\t3.135%\nBond\t2008\t62\t62\t62\tCHF\t2018\t3.135%\nBond\t2009\t56\t56\t0\tAUD\t2013\t5.500%\nBond\t2009\t54\t54\t0\tAUD\t2013\t5.500%\nBond\t2009\t236\t236\t0\tCHF\t2013\t2.500%\nBond\t2009\t77\t77\t0\tUSD\t2013\t4.000%\nBond\t2009\t131\t131\t0\tCHF\t2014\t2.625%\nBond\t2009\t997\t998\t0\tEUR\t2014\t3.500%\nBond\t2009\t150\t150\t0\tEUR\t2014\t3.500%\nBond\t2009\t40\t40\t0\tHKD\t2014\t3.240%\nBond\t2009\t103\t96\t0\tAUD\t2015\t6.000%\nBond\t2009\t550\t550\t0\tEUR\t2015\t3.625%\nBond\t2009\t684\t684\t0\tUSD\t2015\t3.125%\nBond\t2009\t224\t208\t0\tUSD\t2015\t3.125%\nBond\t2009\t99\t99\t0\tCHF\t2016\t2.385%\nBond\t2009\t115\t115\t0\tGBP\t2017\t4.250%\nBond\t2009\t225\t225\t0\tGBP\t2017\t4.250%\nBond\t2009\t448\t448\t0\tEUR\t2019\t4.875%\nBond\t2009\t69\t69\t0\tHKD\t2019\t4.180%\nBond\t2009\t374\t347\t0\tUSD\t2021\t4.250%\nBond\t2010\t102\t\t\tAUD\t2014\t5.750%\nBond\t2010\t108\t\t\tCAD\t2014\t2.500%\nBond\t2010\t53\t\t\tNZD\t2014\t4.750%\nBond\t2010\t187\t\t\tUSD\t2015\t2.875%\nBond\t2010\t935\t\t\tUSD\t2015\t3.000%\nBond\t2010\t748\t\t\tUSD\t2016\t2.300%\nBond\t2010\t68\t\t\tAUD\t2015\t6.000%\nBond\t2010\t69\t\t\tAUD\t2015\t6.000%\nBond\t2010\t64\t\t\tAUD\t2015\t6.000%\nBond\t2010\t476\t\t\tEUR\t2022\t3.125%\nCurrent portion (less than one year)\t\t(3450)\t(1937)\t(722)\t\t\t\nTotal TOTAL CAPITAL\t\t15143\t15615\t13093\t\t\t\nOther consolidated subsidiaries\t\t223\t153\t103\t\t\t\nTotal bonds after fair value hedge\t\t15491\t15884\t13380\t\t\t\n\t\tAmount after hedging as of\t\t\t\t\t\n\tYear of\tDecember 31\tDecember 31\tDecember 31\t\t\tInitial rate before hedging\nFixed rate bonds and bonds after cash flow hedge (M€)\tissue\t2010\t2009\t2008\tCurrency\tMaturity\tinstruments\nTOTAL CAPITAL(a)\t\t\t\t\t\t\t\nBond\t2005\t293\t292\t287\tGBP\t2012\t4.625%\nBond\t2009\t691\t602\t0\tEUR\t2019\t4.875%\nBond\t2009\t917\t806\t0\tEUR\t2024\t5.125%\nBond\t2010\t935\t\t\tUSD\t2020\t4.450%\nTotal fixed rate bonds and bonds after cash flow hedge\t\t2836\t1700\t287\t\t\t\n", "q10k_tbl_231": "\t\tof which hedging\t\t\t\n\t\tinstruments of\tHedging instruments\t\t\n\t\tnon-current\tof non-current\tNon-current financial\t\nAs of December 31 2010\tNon-current\tfinancial debt\tfinancial debt\tdebt - net of hedging\t\n(M€)\tfinancial debt\t(liabilities)\t(assets)\tinstruments\t%\n2012\t3756\t34\t(401)\t3355\t18%\n2013\t4017\t76\t(473)\t3544\t19%\n2014\t2508\t1\t(290)\t2218\t12%\n2015\t3706\t2\t(302)\t3404\t18%\n2016 and beyond\t6796\t65\t(404)\t6392\t33%\nTotal\t20783\t178\t(1870)\t18913\t100%\n", "q10k_tbl_232": "\t\tof which hedging\t\t\t\n\t\tinstruments of\tHedging instruments\t\t\n\t\tnon-current\tof non-current\tNon-current financial\t\nAs of December 31 2009\tNon-current\tfinancial debt\tfinancial debt\tdebt - net of hedging\t\n(M€)\tfinancial debt\t(liabilities)\t(assets)\tinstruments\t%\n2011\t3857\t42\t(199)\t3658\t20%\n2012\t3468\t48\t(191)\t3277\t18%\n2013\t3781\t95\t(236)\t3545\t19%\n2014\t2199\t6\t(90)\t2109\t11%\n2015 and beyond\t6132\t50\t(309)\t5823\t32%\nTotal\t19437\t241\t(1025)\t18412\t100%\n", "q10k_tbl_233": "\t\tof which hedging\t\t\t\n\t\tinstruments of\tHedging instruments\t\t\n\t\tnon-current\tof non-current\tNon-current financial\t\nAs of December 31 2008\tNon-current\tfinancial debt\tfinancial debt\tdebt - net of hedging\t\n(M€)\tfinancial debt\t(liabilities)\t(assets)\tinstruments\t%\n2010\t3160\t170\t(168)\t2992\t20%\n2011\t3803\t24\t(145)\t3658\t24%\n2012\t3503\t115\t(179)\t3324\t22%\n2013\t3430\t127\t(198)\t3232\t21%\n2014 and beyond\t2295\t4\t(202)\t2093\t13%\nTotal\t16191\t440\t(892)\t15299\t100%\n", "q10k_tbl_234": "As of December 31 (M€)\t2010\t%\t2009\t%\t2008\t%\nU.S. Dollar\t7248\t39%\t3962\t21%\t3990\t26%\nEuro\t11417\t60%\t14110\t77%\t10685\t70%\nOther currencies\t248\t1%\t340\t2%\t624\t4%\nTotal\t18913\t100%\t18412\t100%\t15299\t100%\n", "q10k_tbl_235": "As of December 31\t\t\t\t\t\t\n(M€)\t2010\t%\t2009\t%\t2008\t%\nFixed rate\t3177\t17%\t2064\t11%\t633\t4%\nFloating rate\t15736\t83%\t16348\t89%\t14666\t96%\nTotal\t18913\t100%\t18412\t100%\t15299\t100%\n", "q10k_tbl_236": "As of December 31 (M€)\t\t\t\n(Assets) / Liabilities\t2010\t2009\t2008\nCurrent financial debt(a)\t5867\t4761\t5586\nCurrent portion of non-current financial debt\t3786\t2233\t2136\nCurrent borrowings (note 28)\t9653\t6994\t7722\nCurrent portion of hedging instruments of debt (liabilities)\t12\t97\t12\nOther current financial instruments (liabilities)\t147\t26\t146\nOther current financial liabilities (note 28)\t159\t123\t158\nCurrent deposits beyond three months\t(869)\t(55)\t(1)\nCurrent portion of hedging instruments of debt (assets)\t(292)\t(197)\t(100)\nOther current financial instruments (assets)\t(44)\t(59)\t(86)\nCurrent financial assets (note 28)\t(1205)\t(311)\t(187)\nCurrent borrowings and related financial assets and liabilities net\t8607\t6806\t7693\n", "q10k_tbl_237": "As of December 31 (M€)\t\t\t\n(Assets)/Liabilities\t2010\t2009\t2008\nCurrent borrowings\t9653\t6994\t7722\nOther current financial liabilities\t159\t123\t158\nCurrent financial assets\t(1205)\t(311)\t(187)\nNon-current financial debt\t20783\t19437\t16191\nHedging instruments on non-current financial debt\t(1870)\t(1025)\t(892)\nCash and cash equivalents\t(14489)\t(11662)\t(12321)\nNet financial debt\t13031\t13556\t10671\nShareholders' equity-Group share\t60414\t52552\t48992\nEstimated dividend payable\t(2553)\t(2546)\t(2540)\nMinority interest\t857\t987\t958\nTotal shareholder's equity\t58718\t50993\t47410\nNet-debt-to-equity ratio\t22.2%\t26.6%\t22.5%\n", "q10k_tbl_238": "As of December 31 (M€)\t2010\t2009\t2008\nAccruals and deferred income\t184\t223\t151\nPayable to States (including taxes and duties)\t7235\t6024\t6256\nPayroll\t996\t955\t928\nOther operating liabilities\t3574\t4706\t4297\nTotal\t11989\t11908\t11632\n", "q10k_tbl_239": "\tOperating\tFinance\nFor the year ended December 31 2010 (M€)\tleases\tleases\n2011\t582\t39\n2012\t422\t39\n2013\t335\t39\n2014\t274\t35\n2015\t230\t35\n2016 and beyond\t1105\t54\nTotal minimum payments\t2948\t241\nLess financial expenses\t0\t(43)\nNominal value of contracts\t0\t198\nLess current portion of finance lease contracts\t0\t(23)\nOutstanding liability of finance lease contracts\t0\t175\n", "q10k_tbl_240": "\tOperating\tFinance\nFor the year ended December 31 2009 (M€)\tleases\tleases\n2010\t523\t42\n2011\t377\t43\n2012\t299\t42\n2013\t243\t41\n2014\t203\t39\n2015 and beyond\t894\t128\nTotal minimum payments\t2539\t335\nLess financial expenses\t0\t(53)\nNominal value of contracts\t0\t282\nLess current portion of finance lease contracts\t0\t(22)\nOutstanding liability of finance lease contracts\t0\t260\n", "q10k_tbl_241": "\tOperating\tFinance\nFor the year ended December 31 2008 (M€)\tleases\tleases\n2009\t429\t47\n2010\t306\t42\n2011\t243\t42\n2012\t208\t42\n2013\t166\t40\n2014 and beyond\t675\t148\nTotal minimum payments\t2027\t361\nLess financial expenses\t0\t(70)\nNominal value of contracts\t0\t291\nLess current portion of finance lease contracts\t0\t(23)\nOutstanding liability of finance lease contracts\t0\t268\n", "q10k_tbl_242": "\tMaturity and installments\t\t\t\nAs of December 31 2010\t\tLess than 1\tBetween 1\tMore than 5\n(M€)\tTotal\tyear\tand 5 years\tyears\nNon-current debt obligations net of hedging instruments (Note 20)\t18738\t0\t12392\t6346\nCurrent portion of non-current debt obligations net of hedging instruments (Note 20)\t3483\t3483\t0\t0\nFinance lease obligations (Note 22)\t198\t23\t129\t46\nAsset retirement obligations (Note 19)\t5917\t177\t872\t4868\nContractual obligations recorded in the balance sheet\t28336\t3683\t13393\t11260\nOperating lease obligations (Note 22)\t2948\t582\t1261\t1105\nPurchase obligations\t61293\t6347\t14427\t40519\nContractual obligations not recorded in the balance sheet\t64241\t6929\t15688\t41624\nTotal of contractual obligations\t92577\t10612\t29081\t52884\nGuarantees given for excise taxes\t1753\t1594\t71\t88\nGuarantees given against borrowings\t5005\t1333\t493\t3179\nIndemnities related to sales of businesses\t37\t0\t31\t6\nGuarantees of current liabilities\t171\t147\t19\t5\nGuarantees to customers / suppliers\t3020\t1621\t96\t1303\nLetters of credit\t1250\t1247\t0\t3\nOther operating commitments\t2057\t467\t220\t1370\nTotal of other commitments given\t13293\t6409\t930\t5954\nMortgages and liens received\t429\t2\t114\t313\nOther commitments received\t6387\t3878\t679\t1830\nTotal of commitments received\t6816\t3880\t793\t2143\n", "q10k_tbl_243": "\tMaturity and installments\t\t\t\nAs of December 31 2009\t\tLess than 1\tBetween 1\tMore than 5\n(M€)\tTotal\tyear\tand 5 years\tyears\nNon-current debt obligations net of hedging instruments (Note 20)\t18152\t0\t12443\t5709\nCurrent portion of non-current debt obligations net of hedging instruments (Note 20)\t2111\t2111\t0\t0\nFinance lease obligations (Note 22)\t282\t22\t146\t114\nAsset retirement obligations (Note 19)\t5469\t235\t972\t4262\nContractual obligations recorded in the balance sheet\t26014\t2368\t13561\t10085\nOperating lease obligations (Note 22)\t2539\t523\t1122\t894\nPurchase obligations\t49808\t4542\t9919\t35347\nContractual obligations not recorded in the balance sheet\t52347\t5065\t11041\t36241\nTotal of contractual obligations\t78361\t7433\t24602\t46326\nGuarantees given for excise taxes\t1765\t1617\t69\t79\nGuarantees given against borrowings\t2882\t1383\t709\t790\nIndemnities related to sales of businesses\t36\t0\t1\t35\nGuarantees of current liabilities\t203\t160\t38\t5\nGuarantees to customers / suppliers\t2770\t1917\t70\t783\nLetters of credit\t1499\t1485\t2\t12\nOther operating commitments\t765\t582\t103\t80\nTotal of other commitments given\t9920\t7144\t992\t1784\nMortgages and liens received\t330\t5\t106\t219\nOther commitments received\t5637\t3187\t481\t1969\nTotal of commitments received\t5967\t3192\t587\t2188\n", "q10k_tbl_244": "\tMaturity and installments\t\t\t\nAs of December 31 2008\t\tLess than\tBetween 1\tMore than\n(M€)\tTotal\t1 year\tand 5 years\t5 years\nNon-current debt obligations net of hedging instruments (Note 20)\t15031\t0\t13064\t1967\nCurrent portion of non-current debt obligations net of hedging instruments (Note 20)\t2025\t2025\t0\t0\nFinance lease obligations (Note 22)\t291\t23\t142\t126\nAsset retirement obligations (Note 19)\t4500\t154\t653\t3693\nContractual obligations recorded in the balance sheet\t21847\t2202\t13859\t5786\nOperating lease obligations (Note 22)\t2027\t429\t923\t675\nPurchase obligations\t60226\t4420\t13127\t42679\nContractual obligations not recorded in the balance sheet\t62253\t4849\t14050\t43354\nTotal of contractual obligations\t84100\t7051\t27909\t49140\nGuarantees given for excise taxes\t1720\t1590\t58\t72\nGuarantees given against borrowings\t2870\t1119\t519\t1232\nIndemnities related to sales of businesses\t39\t3\t1\t35\nGuarantees of current liabilities\t315\t119\t164\t32\nGuarantees to customers / suppliers\t2866\t68\t148\t2650\nLetters of credit\t1080\t1024\t17\t39\nOther operating commitments\t648\t246\t132\t270\nTotal of other commitments given\t9538\t4169\t1039\t4330\nMortgages and liens received\t321\t72\t110\t139\nOther commitments received\t4218\t2440\t234\t1544\nTotal of commitments received\t4539\t2512\t344\t1683\n", "q10k_tbl_245": "Balance sheet\t\t\t\nAs of December 31 (M€)\t2010\t2009\t2008\nReceivables\t\t\t\nDebtors and other debtors\t432\t293\t244\nLoans (excl. loans to equity affiliates)\t315\t438\t354\nPayables\t\t\t\nCreditors and other creditors\t497\t386\t136\nDebts\t28\t42\t50\n", "q10k_tbl_246": "Statement of income\t\t\t\nFor the year ended December 31\t\t\t\n(M€)\t2010\t2009\t2008\nSales\t3194\t2183\t3082\nPurchases\t5576\t2958\t4061\nFinancial expense\t69\t1\t0\nFinancial income\t74\t68\t114\n", "q10k_tbl_247": "For the year ended December 31\t\t\t\n(M€)\t2010\t2009\t2008\nNumber of people\t26\t27\t30\nDirect or indirect compensation\t20.8\t19.4\t20.4\nPension expenses(a)\t12.2\t10.6\t11.9\nOther long-term benefits\t0\t0\t0\nTermination benefits\t0\t0\t0\nShare-based payments expense (IFRS 2)(b)\t10.0\t11.2\t16.6\n", "q10k_tbl_248": "(a)\tThe benefits provided for executive officers and certain members of the Board of Directors employees and former employees of the Group include severance to be paid on retirement supplementary pension schemes and insurance plans which represent €113.8 million provisioned as of December 31 2010 (against €96.6 million as of December 31 2009 and €98.0 million as of December 31 2008).\n(b)\tShare-based payments expense computed for the executive officers and the members of the Board of Directors who are employees of the Group as described in Note 25 paragraph E to the Consolidated Financial Statements and based on the principles of IFRS 2 \"Share-based payments\" described in Note 1 paragraph E to the Consolidated Financial Statements.\n", "q10k_tbl_249": "\t\t\t\t\t\t\t\t\t\tWeighted\n\t\t\t\t\t\t\t\t\t\taverage\n\t2003\t2004\t2005\t2006\t2007\t2008\t2009\t2010\t\texercise\n\tPlan\tPlan\tPlan\tPlan\tPlan\tPlan\tPlan\tPlan\tTotal\tprice\nDate of the shareholders' meeting\t05/17/2001\t05/14/2004\t05/14/2004\t05/14/2004\t05/11/2007\t05/11/2007\t05/11/2007\t05/21/2010\t\t\nGrant Date(a)\t07/16/2003\t07/20/2004\t07/19/2005\t07/18/2006\t07/17/2007\t10/09/2008\t09/15/2009\t09/14/2010\t\t\nExercise price until May 23 2006 included(b)\t33.30\t39.85\t49.73\t0\t0\t0\t0\t0\t\t\nExercise price since May 24 2006(b)\t32.84\t39.30\t49.04\t50.60\t60.10\t42.90\t39.90\t38.20\t\t\nExpiry date\t07/16/2011\t07/20/2012\t07/19/2013\t07/18/2014\t07/17/2015\t10/09/2016\t09/15/2017\t09/14/2018\t\t\nNumber of options(c)\t\t\t\t\t\t\t\t\t\t\nOutstanding as of January 1 2008\t8368378\t13197236\t6243438\t5711060\t5920105\t\t\t\t39440217\t44.23\nAwarded\t0\t0\t0\t0\t0\t4449810\t\t\t4449810\t42.90\nCanceled\t(25184)\t(118140)\t(34032)\t(53304)\t(34660)\t(6000)\t\t\t(271320)\t44.88\nExercised\t(841846)\t(311919)\t(17702)\t(6700)\t0\t0\t\t\t(1178167)\t34.89\nOutstanding as of January 1 2009\t7501348\t12767177\t6191704\t5651056\t5885445\t4443810\t\t\t42440540\t44.35\nAwarded\t0\t0\t0\t0\t0\t0\t4387620\t\t4387620\t39.90\nCanceled\t(8020)\t(18387)\t(6264)\t(5370)\t(13780)\t(2180)\t(10610)\t\t(64611)\t45.04\nExercised\t(681699)\t(253081)\t0\t0\t0\t0\t0\t\t(934780)\t34.59\nOutstanding as of January 1 2010\t6811629\t12495709\t6185440\t5645686\t5871665\t4441630\t4377010\t\t45828769\t44.12\nAwarded\t0\t0\t0\t0\t0\t0\t0\t4788420\t4788420\t38.20\nCanceled(d)\t(1420)\t(15660)\t(6584)\t(4800)\t(5220)\t(92472)\t(4040)\t(1120)\t(131316)\t43.50\nExercised\t(1075765)\t(141202)\t0\t0\t0\t0\t(1080)\t0\t(1218047)\t33.60\nOutstanding as of December 31 2010\t5734444\t12338847\t6178856\t5640886\t5866445\t4349158\t4371890\t4787300\t49267826\t43.80\n", "q10k_tbl_250": "(a)\tThe grant date is the date of the Board meeting awarding the share subscription options except for the grant of October 9 2008 decided by the Board on September 9 2008.\n(b)\tExercise price in euro. The exercise prices of TOTAL subscription shares of the plans in force at that date were multiplied by 0.25 to take into account the four-for-one stock split on May 18 2006. Moreover following the spin-off of Arkema the exercise prices of TOTAL subscription shares of these plans were multiplied by an adjustment factor equal to 0.986147 effective as of May 24 2006.\n(c)\tThe number of options awarded outstanding canceled or exercised before May 23 2006 included was multiplied by four to take into account the four-for-one stock split approved by the shareholders' meeting on May 12 2006.\n(d)\tOut of 92472 options awarded under the 2008 Plan that were canceled 88532 options were canceled due to the performance condition. The acquisition rate applicable to the subscription options that were subject to the performance condition of the 2008 Plan was 60%.\n", "q10k_tbl_251": "0\tThe first 3000 options two-thirds of the options above the first 3000 options and below the first 50000 options and one-third of the options above the first 50000 options will be finally granted to their beneficiary;\n0\tThe outstanding options that is one-third of the options above the first 3000 options and below the first 50000 options and two-thirds of the options above the first 50000 options will be finally granted provided that the performance condition is fulfilled.\n", "q10k_tbl_252": "0\tFor 50% of the share subscription options granted the performance condition states that the number of options finally granted is based on the average ROE of the Group. The average ROE is calculated by the Group based on TOTAL's consolidated balance sheet and statement of income for fiscal years 2010 and 2011. The acquisition rate is equal to zero if the average ROE is less than or equal to 7%; varies on a straight-line basis between 0% and 100% if the average ROE is more than 7% and less than 18%; and is equal to 100% if the average ROE is more than or equal to 18%.\n0\tFor 50% of the share subscription options granted the performance condition states that the number of options finally granted is based on the average of the Return On Average Capital Employed (ROACE) of the Group. The average ROACE is calculated by the Group based on TOTAL's consolidated balance sheet and statement of income for fiscal years 2010 and 2011. The acquisition rate is equal to zero if the average ROACE is less than or equal to 6%; varies on a straight-line basis between 0% and 100% if the average ROACE is more than 6% and less than 15%; and is equal to 100% if the average ROACE is more than or equal to 15%.\n", "q10k_tbl_253": "0\tFor 50% of the share subscription options granted the performance condition states that the number of options finally granted is based on the average ROE of the Group as published by TOTAL. The average ROE is calculated based on the Group's consolidated balance sheet and statement of income for fiscal years 2009 and 2010. The acquisition rate is equal to zero if the average ROE is less than or equal to 7%; varies on a straight-line basis between 0% and 100% if the average ROE is more than 7% and less than 18%; and is equal to 100% if the average ROE is more than or equal to 18%.\n0\tFor 50% of the share subscription options granted the performance condition states that the number of options finally granted is based on the average ROACE of the Group as published by TOTAL. The average ROACE is calculated based on the Group's consolidated balance sheet and statement of income for fiscal years 2009 and 2010. The acquisition rate is equal to zero if the average ROACE is less than or equal to 6%; varies on a straight-line basis between 0% and 100% if the average ROACE is more than 6% and less than 15%; and is equal to 100% if the average ROACE is more than or equal to 15%.\n", "q10k_tbl_254": "0\tis equal to zero if the ROE is less than or equal to 10%;\n0\tvaries on a straight-line basis between 0% and 80% if the ROE is more than 10% and less than 18%;\n0\tvaries on a straight-line basis between 80% and 100% if the ROE is more than or equal to 18% and less than 30%; and\n0\tis equal to 100% if the ROE is more than or equal to 30%.\n", "q10k_tbl_255": "\t\t\t\t\tWeighted\n\t\t\t\t\taverage\n\t2000 Plan(a)\t2001 Plan(b)\t2002 Plan(c)\tTotal\texercise price\nDate of the shareholders' meeting\t05/21/1997\t05/17/2001\t05/17/2001\t\t\nGrant date(d)\t07/11/2000\t07/10/2001\t07/09/2002\t\t\nExercise price until May 23 2006 included(e)\t40.68\t42.05\t39.58\t\t\nExercise price since May 24 2006(e)\t40.11\t41.47\t39.03\t\t\nExpiry date\t07/11/2008\t07/10/2009\t07/09/2010\t\t\nNumber of options(f)\t\t\t\t\t\nOutstanding as of January 1 2008\t3142188\t5150258\t7063183\t15355629\t40.07\nAwarded\t0\t0\t0\t0\t0\nCanceled\t(480475)\t(3652)\t(13392)\t(497519)\t40.09\nExercised\t(2661713)\t(455180)\t(598934)\t(3715827)\t40.10\nOutstanding as of January 1 2009\t0\t4691426\t6450857\t11142283\t40.06\nAwarded\t\t0\t0\t0\t0\nCanceled\t\t(4650446)\t(7920)\t(4658366)\t41.47\nExercised\t\t(40980)\t(507676)\t(548656)\t39.21\nOutstanding as of January 1 2010\t\t0\t5935261\t5935261\t39.03\nAwarded\t\t\t0\t0\t0\nCanceled(g)\t\t\t(4671989)\t(4671989)\t39.03\nExercised\t\t\t(1263272)\t(1263272)\t39.03\nOutstanding as of December 31 2010\t\t\t0\t0\t0\n", "q10k_tbl_256": "(a)\tOptions were exercisable subject to a continued employment condition after a 4-year vesting period from the date of the Board meeting awarding the options and expired eight years after this date. The underlying shares may not be transferred during the 5-year period from the date of the grant. This plan expired on July 11 2008.\n(b)\tOptions were exercisable subject to a continued employment condition after a 3.5-year vesting period from the date of the Board meeting awarding the options and expired eight years after this date. The underlying shares may not be transferred during the 4-year period from the date of the grant. This plan expired on July 10 2009.\n(c)\tOptions were exercisable subject to a continued employment condition after a 2-year vesting period from the date of the Board meeting awarding the options and expired eight years after this date. The underlying shares may not be transferred during the 4-year period from the date of the grant. This plan expired on July 9 2010.\n(d)\tThe grant date is the date of the Board meeting awarding the options.\n(e)\tExercise price in euro. The exercise prices of TOTAL share purchase options of the plans at that date were multiplied by 0.25 to take into account the four-for-one stock split on May 18 2006. Moreover following the spin-off of Arkema the exercise prices of TOTAL share purchase options of these plans were multiplied by an adjustment factor equal to 0.986147 effective as of May 24 2006.\n(f)\tThe number of options awarded outstanding canceled or exercised before May 23 2006 included was multiplied by four to take into account the four-for-one stock split approved by the shareholders' meeting on May 12 2006.\n(g)\tOut of the 4671989 options canceled in 2010 4671145 options that were not exercised expired due to the expiry of the 2002 purchase option Plan on July 9 2010.\n", "q10k_tbl_257": "\t2005 Plan\t2006 Plan\t2007 Plan\t2008 Plan\t2009 Plan\t2010 Plan\tTotal\nDate of the shareholders' meeting\t05/17/2005\t05/17/2005\t05/17/2005\t05/16/2008\t05/16/2008\t05/16/2008\t\nGrant date(a)\t07/19/2005\t07/18/2006\t07/17/2007\t10/09/2008\t09/15/2009\t09/14/2010\t\nFinal grant date (end of the vesting period)\t07/20/2007\t07/19/2008\t07/18/2009\t10/10/2010\t09/16/2011\t09/15/2012\t\nTransfer possible from\t07/20/2009\t07/19/2010\t07/18/2011\t10/10/2012\t09/16/2013\t09/15/2014\t\nNumber of restricted shares\t\t\t\t\t\t\t\nOutstanding as of January 1 2008\t0\t2263956\t2363057\t\t\t\t4627013\nAwarded\t0\t0\t0\t2791968\t\t\t2791968\nCanceled\t2840\t(43822)\t(29504)\t(19220)\t\t\t(89706)\nFinally granted(b)(c)\t(2840)\t(2220134)\t(336)\t0\t\t\t(2223310)\nOutstanding as of January 1 2009\t0\t0\t2333217\t2772748\t\t\t5105965\nAwarded\t0\t0\t0\t0\t2972018\t\t2972018\nCanceled\t1928\t2922\t(12418)\t(9672)\t(5982)\t\t(23222)\nFinally granted(b)(c)\t(1928)\t(2922)\t(2320799)\t(600)\t0\t\t(2326249)\nOutstanding as of January 1 2010\t0\t0\t0\t2762476\t2966036\t\t5728512\nAwarded\t0\t0\t0\t0\t0\t3010011\t3010011\nCanceled(d)\t1024\t3034\t552\t(1113462)\t(9796)\t(8738)\t(1127386)\nFinally granted(b)(c)\t(1024)\t(3034)\t(552)\t(1649014)\t(1904)\t(636)\t(1656164)\nOutstanding as of December 31 2010\t0\t0\t0\t0\t2954336\t3000637\t5954973\n", "q10k_tbl_258": "(a)\tThe grant date is the date of the Board of Directors meeting that awarded the shares except for the shares awarded by the Board of Directors at their meeting of September 9 2008 and granted on October 9 2008.\n(b)\tRestricted shares finally granted following the death of their beneficiaries (2007 Plan for fiscal year 2008 2008 Plan for fiscal year 2009 2009 Plan for fiscal year 2010).\n(c)\tIncluding restricted shares finally granted for which the entitlement right had been canceled erroneously.\n(d)\tOut of the 1113462 canceled rights to the grant share under the 2008 Plan 1094914 entitlement rights were canceled due to the performance condition. The acquisition rate for the 2008 Plan was 60%.\n", "q10k_tbl_259": "0\tis equal to zero if the ROE is less than or equal to 10%;\n0\tvaries on a straight-line basis between 0% and 80% if the ROE is greater than 10% and less than 18%;\n0\tvaries on a straight-line basis between 80% and 100% if the ROE is greater than or equal to 18% and less than 30%; and\n0\tis equal to 100% if the ROE is greater than or equal to 30%.\n", "q10k_tbl_260": "\t2010 Plan\t2010 Plan\t\n\t(2+2)\t(4+0)\tTotal\nDate of the shareholders' meeting\t05/16/2008\t05/16/2008\t\nGrant date(a)\t06/30/2010\t06/30/2010\t\nFinal grant date (end of the vesting period)\t07/01/2012\t07/01/2014\t\nTransfer possible from\t07/01/2014\t07/01/2014\t\nNumber of free shares\t\t\t\nOutstanding as of January 1 2008\t\t\t\nAwarded\t\t\t\nCanceled\t\t\t\nFinally granted\t\t\t\nOutstanding as of January 1 2009\t\t\t\nAwarded\t\t\t\nCanceled\t\t\t\nFinally granted\t\t\t\nOutstanding as of January 1 2010\t\t\t\nAwarded\t1508850\t1070650\t2579500\nCanceled\t(125)\t(75)\t(200)\nFinally granted(b)\t(75)\t0\t(75)\nOutstanding as of December 31 2010\t1508650\t1070575\t2579225\n", "q10k_tbl_261": "0\t€61 million for TOTAL share subscription plans;\n0\t€105 million for TOTAL restricted shares plans; and\n0\t€(12) million for the adjustment to the expense booked in 2007 related to TOTAL capital increase reserved for employees (see Note 17 to the Consolidated Financial Statements).\n", "q10k_tbl_262": "For the year ended December 31\t2010\t2009\t2008\nRisk free interest rate (%)(a)\t2.1\t2.9\t4.3\nExpected dividends (%)(b)\t5.9\t4.8\t8.4\nExpected volatility (%)(c)\t25.0\t31.0\t32.7\nVesting period (years)\t2\t2\t2\nExercise period (years)\t8\t8\t8\nFair value of the granted options (€ per option)\t5.8\t8.4\t5.0\n", "q10k_tbl_263": "For the year ended December 31 (M€)\t2010\t2009\t2008\nPersonnel expenses\t\t\t\nWages and salaries (including social charges)\t6246\t6177\t6014\nGroup employees\t\t\t\nFrance\t\t\t\n- Management\t10852\t10906\t10688\n- Other\t24317\t25501\t26413\nInternational\t\t\t\n- Management\t15146\t15243\t14709\n- Other\t42540\t44737\t45149\nTotal\t92855\t96387\t96959\n", "q10k_tbl_264": "For the year ended December 31 (M€)\t2010\t2009\t2008\nInterests paid\t(470)\t(678)\t(958)\nInterests received\t132\t148\t505\nIncome tax paid\t(6990)\t(6202)\t(10631)\nDividends received\t1722\t1456\t1590\n", "q10k_tbl_265": "For the year ended December 31 (M€)\t2010\t2009\t2008\nInventories\t(1896)\t(4217)\t4020\nAccounts receivable\t(2712)\t(344)\t3222\nOther current assets\t911\t1505\t(982)\nAccounts payable\t2482\t571\t(3056)\nOther creditors and accrued liabilities\t719\t(831)\t(633)\nNet amount\t(496)\t(3316)\t2571\n", "q10k_tbl_266": "For the year ended December 31 (M€)\t2010\t2009\t2008\nIssuance of non-current debt\t3995\t6309\t5513\nRepayment of non-current debt\t(206)\t(787)\t(2504)\nNet amount\t3789\t5522\t3009\n", "q10k_tbl_267": "For the year ended December 31 (M€)\t2010\t2009\t2008\nCash\t4679\t2448\t1836\nCash equivalents\t9810\t9214\t10485\nTotal\t14489\t11662\t12321\n", "q10k_tbl_268": "\t\t\t\t\t\t\t\tOther financial\t\tFair\n\tFinancial instruments related to financing and trading activities\t\t\t\t\t\t\tinstruments\tTotal\tvalue\nAs of December 31 2010\tAmortized\tFair\t\t\t\t\t\t\t\t\n(M€)\tcost\tvalue\t\t\t\t\t\t\t\t\nAssets /\t\tAvailable\tHeld for\t\tHedging of\tCash\tNet investment\t\t\t\n(Liabilities)\t\tfor sale(a)\ttrading\tFinancial debt(b)\tfinancial debt\tflow hedge\thedge and other\t\t\t\nEquity affiliates:\t\t\t\t\t\t\t\t\t\t\nloans\t2383\t\t\t\t\t\t\t\t2383\t2383\nOther investments\t\t4590\t\t\t\t\t\t\t4590\t4590\nHedging instruments of non-current financial debt\t\t\t\t\t1814\t56\t\t\t1870\t1870\nOther non-current assets\t1596\t\t\t\t\t\t\t\t1596\t1596\nAccounts receivable net\t\t\t\t\t\t\t\t18159\t18159\t18159\nOther operating receivables\t\t\t499\t\t\t\t\t3908\t4407\t4407\nCurrent financial assets\t869\t\t38\t\t292\t\t6\t\t1205\t1205\nCash and cash equivalents\t\t\t\t\t\t\t\t14489\t14489\t14489\nTotal financial assets\t4848\t4590\t537\t0\t2106\t56\t6\t36556\t48699\t48699\nTotal non-financial assets\t\t\t\t\t\t\t\t\t95019\t\nTotal assets\t\t\t\t\t\t\t\t\t143718\t\nNon-current financial\t(3186)\t\t\t(17419)\t(178)\t\t\t\t(20783)\t(21172)\ndebt\t\t\t\t\t\t\t\t\t\t\nAccounts payable\t\t\t\t\t\t\t\t(18450)\t(18450)\t(18450)\nOther operating\t\t\t(559)\t\t\t\t\t(3015)\t(3574)\t(3574)\nliabilities\t\t\t\t\t\t\t\t\t\t\nCurrent borrowings\t(5916)\t\t\t(3737)\t\t\t\t\t(9653)\t(9653)\nOther current financial liabilities\t\t\t(147)\t\t(12)\t\t0\t\t(159)\t(159)\nTotal financial liabilities\t(9102)\t\t(706)\t(21156)\t(190)\t0\t0\t(21465)\t(52619)\t(53008)\nTotal non-financial liabilities\t\t\t\t\t\t\t\t\t(91099)\t\nTotal liabilities\t\t\t\t\t\t\t\t\t(143718)\t\n", "q10k_tbl_269": "\t\t\t\t\t\t\t\tOther financial\t\tFair\n\tFinancial instruments related to financing and trading activities\t\t\t\t\t\t\tinstruments\tTotal\tvalue\nAs of December 31 2009\tAmortized\tFair\t\t\t\t\t\t\t\t\n(M€)\tcost\tvalue\t\t\t\t\t\t\t\t\nAssets /\t\tAvailable\tHeld for\t\tHedging of\tCash\tNet investment\t\t\t\n(Liabilities)\t\tfor sale(a)\ttrading\tFinancial debt(b)\tfinancial debt\tflow hedge\thedge and other\t\t\t\nEquity affiliates:\t\t\t\t\t\t\t\t\t\t\nloans\t2367\t\t\t\t\t\t\t\t2367\t2367\nOther investments\t\t1162\t\t\t\t\t\t\t1162\t1162\nHedging instruments of non-current financial debt\t\t\t\t\t889\t136\t\t\t1025\t1025\nOther non-current assets\t1284\t\t\t\t\t\t\t\t1284\t1284\nAccounts receivable net\t\t\t\t\t\t\t\t15719\t15719\t15719\nOther operating receivables\t\t\t1029\t\t\t\t\t4116\t5145\t5145\nCurrent financial assets\t55\t\t53\t\t197\t\t6\t\t311\t311\nCash and cash equivalents\t\t\t\t\t\t\t\t11662\t11662\t11662\nTotal financial assets\t3706\t1162\t1082\t0\t1086\t136\t6\t31497\t38675\t38675\nTotal non-financial assets\t\t\t\t\t\t\t\t\t89078\t\nTotal assets\t\t\t\t\t\t\t\t\t127753\t\nNon-current financial debt\t(2089)\t\t\t(17107)\t(241)\t\t\t\t(19437)\t(19905)\nAccounts payable\t\t\t\t\t\t\t\t(15383)\t(15383)\t(15383)\nOther operating liabilities\t\t\t(923)\t\t\t\t\t(3783)\t(4706)\t(4706)\nCurrent borrowings\t(4849)\t\t\t(2145)\t\t\t\t\t(6994)\t(6994)\nOther current financial liabilities\t\t\t(25)\t\t(97)\t\t(1)\t\t(123)\t(123)\nTotal financial liabilities\t(6938)\t\t(948)\t(19252)\t(338)\t0\t(1)\t(19166)\t(46643)\t(47111)\nTotal non-financial liabilities\t\t\t\t\t\t\t\t\t(81110)\t\nTotal liabilities\t\t\t\t\t\t\t\t\t(127753)\t\n", "q10k_tbl_270": "\t\t\t\t\t\t\t\tOther financial\t\tFair\n\tFinancial instruments related to financing and trading activities\t\t\t\t\t\t\tinstruments\tTotal\tvalue\nAs of December 31 2008\tAmortized\tFair\t\t\t\t\t\t\t\t\n(M€)\tcost\tvalue\t\t\t\t\t\t\t\t\nAssets /\t\tAvailable\tHeld for\t\tHedging of\t\tNet investment\t\t\t\n(Liabilities)\t\tfor sale(a)\ttrading\tFinancial debt(b)\tfinancial debt\tCash flow hedge\thedge and other\t\t\t\nEquity affiliates:\t\t\t\t\t\t\t\t\t\t\nloans\t2005\t\t\t\t\t\t\t\t2005\t2005\nOther investments\t\t1165\t\t\t\t\t\t\t1165\t1165\nHedging instruments of non-current financial debt\t\t\t\t\t892\t\t\t\t892\t892\nOther non-current assets\t1403\t\t\t\t\t\t\t\t1403\t1403\nAccounts receivable net\t\t\t0\t\t\t\t\t15287\t15287\t15287\nOther operating receivables\t\t\t1664\t\t\t\t\t4544\t6208\t6208\nCurrent financial assets\t1\t\t86\t\t100\t\t0\t\t187\t187\nCash and cash\t\t\t\t\t\t\t\t12321\t12321\t12321\nequivalents\t\t\t\t\t\t\t\t\t\t\nTotal financial assets\t3409\t1165\t1750\t0\t992\t0\t0\t32152\t39468\t39468\nTotal non-financial assets\t\t\t\t\t\t\t\t\t78842\t\nTotal assets\t\t\t\t\t\t\t\t\t118310\t\nNon-current financial debt\t(701)\t\t\t(15050)\t(440)\t\t\t\t(16191)\t(16191)\nAccounts payable\t\t\t0\t\t\t\t\t(14815)\t(14815)\t(14815)\nOther operating liabilities\t\t\t(1033)\t\t\t\t\t(3264)\t(4297)\t(4297)\nCurrent borrowings\t(5721)\t\t\t(2001)\t\t\t\t\t(7722)\t(7722)\nOther current financial liabilities\t\t\t(146)\t\t(12)\t\t\t\t(158)\t(158)\nTotal financial liabilities\t(6422)\t\t(1179)\t(17051)\t(452)\t0\t0\t(18079)\t(43183)\t(43183)\nTotal non-financial liabilities\t\t\t\t\t\t\t\t\t(75127)\t\nTotal liabilities\t\t\t\t\t\t\t\t\t(118310)\t\n", "q10k_tbl_271": "For the year ended December 31\t\t\t\n(M€)\t2010\t2009\t2008\nAssets available for sale (investments):\t\t\t\n- Dividend income on non-consolidated subsidiaries\t255\t210\t238\n- Gains (losses) on disposal of assets\t60\t6\t15\n- Other\t(17)\t(18)\t(15)\nLoans and receivables\t90\t41\t100\nImpact on net operating income\t388\t239\t338\n", "q10k_tbl_272": "For the year ended December 31\t\t\t\n(M€)\t2010\t2009\t2008\nLoans and receivables\t133\t158\t547\nFinancing liabilities and associated hedging instruments\t(469)\t(563)\t(996)\nFair value hedge (ineffective portion)\t4\t33\t(4)\nAssets and liabilities held for trading\t(2)\t(26)\t(74)\nImpact on the cost of net debt\t(334)\t(398)\t(527)\n", "q10k_tbl_273": "For the year ended December 31\t\t\t\n(M€)\t2010\t2009\t2008\nRevaluation at market value of\t\t\t\nbonds\t(1164)\t(183)\t(66)\nSwap hedging of bonds\t1168\t216\t62\nIneffective portion of the fair value hedge\t4\t33\t(4)\n", "q10k_tbl_274": "For the year ended December 31 (M€)\tAs of January 1\tVariations\tDisposals\tAs of December 31\n2010\t25\t(268)\t0\t(243)\n2009\t124\t(99)\t0\t25\n2008\t29\t95\t0\t124\n", "q10k_tbl_275": "For The year ended December 31 (M€)\t2010\t2009\t2008\nProfit (Loss) recorded in equity during the period\t(80)\t128\t0\nRecycled amount from equity to the income statement during the period\t(115)\t221\t0\n", "q10k_tbl_276": "As of December 31 2010 (M€)\t\tNotional value(a)\t\t\t\t\t\t\n\t\t\t\t\t\t\t\t2016\n\tFair\t\t\t\t\t\t\tand\nASSETS/(LIABILITIES)\tvalue\tTotal\t2011\t2012\t2013\t2014\t2015\tafter\nFair value hedge\t\t\t\t\t\t\t\t\nSwaps hedging fixed-rates bonds (liabilities)\t(178)\t2244\t\t\t\t\t\t\nSwaps hedging fixed-rates bonds (assets)\t1814\t13939\t\t\t\t\t\t\nTotal swaps hedging fixed-rates bonds (assets and liabilities)\t1636\t16183\t\t2967\t3461\t2421\t3328\t4006\nSwaps hedging fixed-rates bonds (current portion) (liabilities)\t(12)\t592\t\t\t\t\t\t\nSwaps hedging fixed-rates bonds (current portion) (assets)\t292\t2815\t\t\t\t\t\t\nTotal swaps hedging fixed-rates bonds (current portion) (assets and liabilities)\t280\t3407\t3407\t\t\t\t\t\nCash flow hedge\t\t\t\t\t\t\t\t\nSwaps hedging fixed-rates bonds (liabilities)\t0\t0\t\t\t\t\t\t\nSwaps hedging fixed-rates bonds (assets)\t56\t1957\t\t\t\t\t\t\nTotal swaps hedging fixed-rates bonds (assets and liabilities)\t56\t1957\t\t295\t\t\t\t1662\nSwaps hedging fixed-rates bonds (current portion) (liabilities)\t\t\t\t\t\t\t\t\nSwaps hedging fixed-rates bonds (current portion) (assets)\t\t\t\t\t\t\t\t\nTotal swaps hedging fixed-rates bonds (current portion) (assets and liabilities)\t0\t0\t0\t\t\t\t\t\nNet investment hedge\t\t\t\t\t\t\t\t\nCurrency swaps and forward exchange contracts (assets)\t6\t381\t\t\t\t\t\t\nCurrency swaps and forward exchange contracts (liabilities)\t0\t0\t\t\t\t\t\t\nTotal swaps hedging net investments\t6\t381\t381\t\t\t\t\t\nHeld for trading\t\t\t\t\t\t\t\t\nOther interest rate swaps (assets)\t1\t6463\t\t\t\t\t\t\nOther interest rate swaps (liabilities)\t(3)\t11395\t\t\t\t\t\t\nTotal other interest rate swaps (assets and liabilities)\t(2)\t17858\t17667\t189\t0\t0\t2\t0\nCurrency swaps and forward exchange contracts (assets)\t37\t1532\t\t\t\t\t\t\nCurrency swaps and forward exchange contracts (liabilities)\t(144)\t6757\t\t\t\t\t\t\nTotal currency swaps and forward exchange contracts (assets and liabilities)\t(107)\t8289\t8102\t0\t25\t49\t31\t82\n", "q10k_tbl_277": "As of December 31 2009 (M€)\t\tNotional value(a)\t\t\t\t\t\t\n\t\t\t\t\t\t\t\t2015\n\tFair\t\t\t\t\t\t\tand\nASSETS/(LIABILITIES)\tvalue\tTotal\t2010\t2011\t2012\t2013\t2014\tafter\nFair value hedge\t\t\t\t\t\t\t\t\nSwaps hedging fixed-rates bonds (liabilities)\t(241)\t4615\t\t\t\t\t\t\nSwaps hedging fixed-rates bonds (assets)\t889\t11076\t\t\t\t\t\t\nTotal swaps hedging fixed-rates bonds (assets and liabilities)\t648\t15691\t0\t3345\t2914\t3450\t1884\t4098\nSwaps hedging fixed-rates bonds (current portion) (liabilities)\t(97)\t912\t\t\t\t\t\t\nSwaps hedging fixed-rates bonds (current portion) (assets)\t197\t1084\t\t\t\t\t\t\nTotal swaps hedging fixed-rates bonds (current portion) (assets and liabilities)\t100\t1996\t1996\t\t\t\t\t\nCash flow hedge\t\t\t\t\t\t\t\t\nSwaps hedging fixed-rates bonds (liabilities) Swaps hedging fixed-rates bonds (assets)\t136\t1837\t\t\t295\t\t\t1542\nTotal swaps hedging fixed-rates bonds (assets and liabilities)\t136\t1837\t\t\t295\t\t\t1542\nSwaps hedging fixed-rates bonds (current portion) (liabilities) Swaps hedging fixed-rates bonds (current portion) (assets)\t\t\t\t\t\t\t\t\nTotal swaps hedging fixed-rates bonds (current portion) (assets and liabilities)\t\t\t\t\t\t\t\t\nNet investment hedge\t\t\t\t\t\t\t\t\nCurrency swaps and forward exchange contracts (assets)\t6\t701\t\t\t\t\t\t\nCurrency swaps and forward exchange contracts (liabilities)\t(1)\t224\t\t\t\t\t\t\nTotal swaps hedging net investments\t5\t925\t925\t\t\t\t\t\nHeld for trading\t\t\t\t\t\t\t\t\nOther interest rate swaps (assets)\t\t1459\t\t\t\t\t\t\nOther interest rate swaps (liabilities)\t(1)\t10865\t\t\t\t\t\t\nTotal other interest rate swaps (assets and liabilities)\t(1)\t12324\t12208\t114\t\t\t\t2\nCurrency swaps and forward exchange contracts (assets)\t53\t4017\t\t\t\t\t\t\nCurrency swaps and forward exchange contracts (liabilities)\t(24)\t3456\t\t\t\t\t\t\nTotal currency swaps and forward exchange contracts (assets and liabilities)\t29\t7473\t7224\t\t52\t50\t47\t100\n", "q10k_tbl_278": "As of December 31 2008 (M€)\t\tNotional value(a)\t\t\t\t\t\t\n\t\t\t\t\t\t\t\t2014\n\tFair\t\t\t\t\t\t\tand\nASSETS/(LIABILITIES)\tvalue\tTotal\t2009\t2010\t2011\t2012\t2013\tafter\nFair value hedge\t\t\t\t\t\t\t\t\nSwaps hedging fixed-rates bonds (liabilities)\t(440)\t9309\t\t\t\t\t\t\nSwaps hedging fixed-rates bonds (assets)\t892\t4195\t\t\t\t\t\t\nTotal swaps hedging fixed-rates bonds (assets and liabilities)\t452\t13504\t0\t2048\t3373\t3233\t3032\t1818\nSwaps hedging fixed-rates bonds (current portion) (liabilities)\t(12)\t92\t\t\t\t\t\t\nSwaps hedging fixed-rates bonds (current portion) (assets)\t100\t1871\t\t\t\t\t\t\nTotal swaps hedging fixed-rates bonds (current portion) (assets and liabilities)\t88\t1963\t1963\t\t\t\t\t\nNet investment hedge\t\t\t\t\t\t\t\t\nCurrency swaps and forward exchange contracts (liabilities)\t0\t1347\t1347\t\t\t\t\t\nHeld for trading\t\t\t\t\t\t\t\t\nOther interest rate swaps (assets)\t0\t2853\t\t\t\t\t\t\nOther interest rate swaps (liabilities)\t(4)\t5712\t\t\t\t\t\t\nTotal other interest rate swaps (assets and liabilities)\t(4)\t8565\t8559\t4\t\t\t\t2\nCurrency swaps and forward exchange contracts (assets)\t86\t5458\t\t\t\t\t\t\nCurrency swaps and forward exchange contracts (liabilities)\t(142)\t2167\t\t\t\t\t\t\nTotal currency swaps and forward exchange contracts (assets and liabilities)\t(56)\t7625\t6595\t483\t114\t67\t76\t290\n", "q10k_tbl_279": "\tQuoted prices in\t\t\t\n\tactive markets\t\tPrices based on\t\n\tfor identical\tPrices based on\tnon observable\t\n\tassets\tobservable data\tdata\t\nAs of December 31 2010 (M€)\t(level 1)\t(level 2)\t(level 3)\tTotal\nFair value hedge instruments\t0\t1916\t0\t1916\nCash flow hedge instruments\t0\t56\t0\t56\nNet investment hedge instruments\t0\t6\t0\t6\nAssets and liabilities held for trading\t0\t(109)\t0\t(109)\nAssets available for sale\t3631\t0\t0\t3631\nTotal\t3631\t1869\t0\t5500\n", "q10k_tbl_280": "\tQuoted prices in\t\t\t\n\tactive markets\t\tPrices based on\t\n\tfor identical\tPrices based on\tnon observable\t\n\tassets\tobservable data\tdata\t\nAs of December 31 2009 (M€)\t(level 1)\t(level 2)\t(level 3)\tTotal\nFair value hedge instruments\t0\t748\t0\t748\nCash flow hedge instruments\t0\t136\t0\t136\nNet investment hedge instruments\t0\t5\t0\t5\nAssets and liabilities held for trading\t0\t28\t0\t28\nAssets available for sale\t232\t0\t0\t232\nTotal\t232\t917\t0\t1149\n", "q10k_tbl_281": "As of December 31 2010 (M€)\t\t\n\tCarrying\tFair\nAssets/(Liabilities)\tamount\tvalue(b)\nCrude oil petroleum products and freight rates activities\t\t\nPetroleum products and crude oil swaps\t(2)\t(2)\nFreight rate swaps\t0\t0\nForwards(a)\t5\t5\nOptions\t51\t51\nFutures\t(12)\t(12)\nOptions on futures\t(4)\t(4)\nTotal crude oil petroleum products and freight rates\t38\t38\nGas & Power activities\t\t\nSwaps\t(1)\t(1)\nForwards(a)\t(102)\t(102)\nOptions\t5\t5\nFutures\t0\t0\nTotal Gas & Power\t(98)\t(98)\nTotal\t(60)\t(60)\nTotal of fair value non recognized in the balance sheet\t\t0\n", "q10k_tbl_282": "As of December 31 2009 (M€)\t\t\n\tCarrying\tFair\nASSETS/(LIABILITIES)\tamount\tvalue(b)\nCrude oil petroleum products and freight rates activities\t\t\nPetroleum products and crude oil swaps\t(29)\t(29)\nFreight rate swaps\t0\t0\nForwards(a)\t(9)\t(9)\nOptions\t21\t21\nFutures\t(17)\t(17)\nOptions on futures\t6\t6\nTotal crude oil petroleum products and freight rates\t(28)\t(28)\nGas & Power activities\t\t\nSwaps\t52\t52\nForwards(a)\t78\t78\nOptions\t4\t4\nFutures\t0\t0\nTotal Gas & Power\t134\t134\nTotal\t106\t106\nTotal of fair value non recognized in the balance sheet\t\t0\n", "q10k_tbl_283": "As of December 31 2008 (M€)\t\t\n\tCarrying\tFair\nASSETS/(LIABILITIES)\tamount\tvalue(b)\nCrude oil petroleum products and freight rates activities\t\t\nPetroleum products and crude oil swaps\t141\t141\nFreight rate swaps\t8\t8\nForwards(a)\t(120)\t(120)\nOptions\t0\t0\nFutures\t17\t17\nOptions on futures\t(7)\t(7)\nTotal crude oil petroleum products and freight rates\t39\t39\nGas & Power activities\t\t\nSwaps\t(48)\t(48)\nForwards(a)\t659\t659\nOptions\t0\t0\nFutures\t(19)\t(19)\nTotal Gas & Power\t592\t592\nTotal\t631\t631\nTotal of fair value non recognized in the balance sheet\t\t0\n", "q10k_tbl_284": "\tFair value as\tImpact on\tSettled\t\tFair value as\nFor the year ended December 31 (M€)\tof January 1\tincome\tcontracts\tOther\tof December 31\nCrude oil petroleum products and freight rates activities\t\t\t\t\t\n2010\t(28)\t1556\t(1488)\t(2)\t38\n2009\t39\t1713\t(1779)\t(1)\t(28)\n2008\t18\t1734\t(1715)\t2\t39\nGas & Power activities\t\t\t\t\t\n2010\t134\t410\t(648)\t6\t(98)\n2009\t592\t327\t(824)\t39\t134\n2008\t232\t787\t(310)\t(117)\t592\n", "q10k_tbl_285": "\tQuoted prices\tPrices based\tPrices based\t\n\tin active\ton\ton non\t\n\tmarkets for\tobservable\tobservable\t\n\tidentical assets\tdata\tdata\t\nAs of December 31 2010 (M€)\t(level 1)\t(level 2)\t(level 3)\tTotal\nCrude oil petroleum products and freight rates activities\t(10)\t48\t0\t38\nGas & Power activities\t50\t(148)\t0\t(98)\nTotal\t40\t(100)\t0\t(60)\n", "q10k_tbl_286": "\tQuoted prices\tPrices based\tPrices based\t\n\tin active\ton\ton non\t\n\tmarkets for\tobservable\tobservable\t\n\tidentical assets\tdata\tdata\t\nAs of December 31 2009 (M€)\t(level 1)\t(level 2)\t(level 3)\tTotal\nCrude oil petroleum products and freight rates activities\t(45)\t17\t0\t(28)\nGas & Power activities\t140\t(6)\t0\t134\nTotal\t95\t11\t0\t106\n", "q10k_tbl_287": "As of December 31\t\t\t\tYear\n(M€)\tHigh\tLow\tAverage\tend\n2010\t23.1\t3.4\t8.9\t3.8\n2009\t18.8\t5.8\t10.2\t7.6\n2008\t13.5\t2.8\t6.9\t11.8\n", "q10k_tbl_288": "As of December 31\t\t\t\tYear\n(M€)\tHigh\tLow\tAverage\tend\n2010\t13.9\t2.7\t6.8\t10.0\n2009\t9.8\t1.9\t5.0\t4.8\n2008\t16.3\t1.3\t5.0\t1.4\n", "q10k_tbl_289": "ASSETS/(LIABILITIES)\t\t\tChange in fair value due to a\t\n(M€)\tCarrying\tEstimated\tchange in interest rate by\t\nAs of December 31 2010\tamount\tfair value\t+ 10 basis points\t- 10 basis points\nBonds (non-current portion before swaps)\t(20019)\t(20408)\t86\t(84)\nSwaps hedging fixed-rates bonds (liabilities)\t(178)\t(178)\t\t\nSwaps hedging fixed-rates bonds (assets)\t1870\t1870\t\t\nTotal swaps hedging fixed-rates bonds (assets and liabilities)\t1692\t1692\t(59)\t59\nCurrent portion of non-current debt after swap (excluding capital lease obligations)\t3483\t3483\t4\t(4)\nOther interest rates swaps\t(2)\t(2)\t3\t(3)\nCurrency swaps and forward exchange contracts\t(101)\t(101)\t0\t0\nAs of December 31 2009\t\t\t\t\nBonds (non-current portion before swaps)\t(18368)\t(18836)\t75\t(75)\nSwaps hedging fixed-rates bonds (liabilities)\t(241)\t(241)\t\t\nSwaps hedging fixed-rates bonds (assets)\t1025\t1025\t\t\nTotal swaps hedging fixed-rates bonds (assets and liabilities)\t784\t784\t(57)\t57\nCurrent portion of non-current debt after swap (excluding capital lease obligations)\t(2111)\t(2111)\t3\t(3)\nOther interest rates swaps\t(1)\t(1)\t1\t(1)\nCurrency swaps and forward exchange contracts\t34\t34\t0\t0\nAs of December 31 2008\t\t\t\t\nBonds (non-current portion before swaps)\t(14119)\t(14119)\t47\t(43)\nSwaps hedging fixed-rates bonds (liabilities)\t(440)\t(440)\t\t\nSwaps hedging fixed-rates bonds (assets)\t892\t892\t\t\nTotal swaps hedging fixed-rates bonds (assets and liabilities)\t452\t452\t(44)\t44\nCurrent portion of non-current debt after swap (excluding capital lease obligations)\t(2025)\t(2025)\t3\t(3)\nOther interest rates swaps\t(4)\t(4)\t1\t(1)\nCurrency swaps and forward exchange contracts\t(56)\t(56)\t0\t0\n", "q10k_tbl_290": "For The year ended December 31 (M€)\t2010\t2009\t2008\nCost of net debt\t(334)\t(398)\t(527)\nInterest rate translation of :\t\t\t\n+ 10 basis points\t(11)\t(11)\t(11)\n- 10 basis points\t11\t11\t11\n+ 100 basis points\t(107)\t(108)\t(113)\n- 100 basis points\t107\t108\t113\n", "q10k_tbl_291": "\tEuro / Dollar\tEuro / Pound sterling\n\texchange rates\texchange rates\nAs of December 31 2010\t1.34\t0.86\nAs of December 31 2009\t1.44\t0.89\nAs of December 31 2008\t1.39\t0.95\n", "q10k_tbl_292": "\t\t\t\t\tOther\n\t\t\t\t\tcurrencies\n\t\t\t\tPound\tand equity\nAs of December 31 2010 (M€)\tTotal\tEuro\tDollar\tsterling\taffiliates(a)\nShareholders' equity at historical exchange rate\t62909\t32894\t22242\t4997\t2776\nCurrency translation adjustment before net investment hedge\t(2501)\t0\t(1237)\t(1274)\t10\nNet investment hedge - open instruments\t6\t0\t6\t0\t0\nShareholders' equity at exchange rate as of December 31 2010\t60414\t32894\t21011\t3723\t2786\n", "q10k_tbl_293": "\t\t\t\t\tOther\n\t\t\t\t\tcurrencies\n\t\t\t\tPound\tand equity\nAs of December 31 2009 (M€)\tTotal\tEuro\tDollar\tsterling\taffiliates\nShareholders' equity at historical exchange rate\t57621\t27717\t18671\t5201\t6032\nCurrency translation adjustment before net investment hedge\t(5074)\t0\t(3027)\t(1465)\t(582)\nNet investment hedge - open instruments\t5\t0\t6\t(1)\t0\nShareholders' equity at exchange rate as of December 31 2009\t52552\t27717\t15650\t3735\t5450\n", "q10k_tbl_294": "\t\t\t\t\tOther\n\t\t\t\t\tcurrencies\n\t\t\t\tPound\tand equity\nAs of December 31 2008 (M€)\tTotal\tEuro\tDollar\tsterling\taffiliates\nShareholders' equity at historical exchange rate\t53868\t25084\t15429\t5587\t7768\nCurrency translation adjustment before net investment hedge\t(4876)\t0\t(2191)\t(1769)\t(916)\nNet investment hedge - open instruments\t0\t0\t0\t0\t0\nShareholders' equity at exchange rate as of December 31 2008\t48992\t25084\t13238\t3818\t6852\n", "q10k_tbl_295": "As of December 31 2010 (M€)\tLess than\t\t\t\t\tMore than\t\nASSETS/(LIABILITIES)\tone year\t1-2 years\t2-3 years\t3-4 years\t4-5 years\t5 years\tTotal\nNon-current financial debt (notional value excluding interests)\t\t(3355)\t(3544)\t(2218)\t(3404)\t(6392)\t(18913)\nCurrent borrowings\t(9653)\t\t\t\t\t\t(9653)\nOther current financial liabilities\t(159)\t\t\t\t\t\t(159)\nCurrent financial assets\t1205\t\t\t\t\t\t1205\nCash and cash equivalents\t14489\t\t\t\t\t\t14489\nNet amount before financial expense\t5882\t(3355)\t(3544)\t(2218)\t(3404)\t(6392)\t(13031)\nFinancial expense on non-current financial debt\t(843)\t(729)\t(605)\t(450)\t(358)\t(1195)\t(4180)\nInterest differential on swaps\t461\t334\t153\t33\t2\t(78)\t905\nNet amount\t5500\t(3750)\t(3996)\t(2635)\t(3760)\t(7665)\t(16306)\n", "q10k_tbl_296": "As of December 31 2009 (M€)\tLess than\t\t\t\t\tMore than\t\nASSETS/(LIABILITIES)\tone year\t1-2 years\t2-3 years\t3-4 years\t4-5 years\t5 years\tTotal\nNon-current financial debt (notional value excluding interests)\t\t(3658)\t(3277)\t(3545)\t(2109)\t(5823)\t(18412)\nCurrent borrowings\t(6994)\t\t\t\t\t\t(6994)\nOther current financial liabilities\t(123)\t\t\t\t\t\t(123)\nCurrent financial assets\t311\t\t\t\t\t\t311\nCash and cash equivalents\t11662\t\t\t\t\t\t11662\nNet amount before financial expense\t4856\t(3658)\t(3277)\t(3545)\t(2109)\t(5823)\t(13556)\nFinancial expense on non-current financial debt\t(768)\t(697)\t(561)\t(448)\t(301)\t(1112)\t(3887)\nInterest differential on swaps\t447\t233\t100\t25\t(16)\t(55)\t734\nNet amount\t4535\t(4122)\t(3738)\t(3968)\t(2426)\t(6990)\t(16709)\n", "q10k_tbl_297": "As of December 31 2008 (M€)\tLess than\t\t\t\t\tMore than\t\nASSETS/(LIABILITIES)\tone year\t1-2 years\t2-3 years\t3-4 years\t4-5 years\t5 years\tTotal\nNon-current financial debt (notional value excluding interests)\t\t(2992)\t(3658)\t(3324)\t(3232)\t(2093)\t(15299)\nCurrent borrowings\t(7722)\t\t\t\t\t\t(7722)\nOther current financial liabilities\t(158)\t\t\t\t\t\t(158)\nCurrent financial assets\t187\t\t\t\t\t\t187\nCash and cash equivalents\t12321\t\t\t\t\t\t12321\nNet amount before financial expense\t4628\t(2992)\t(3658)\t(3324)\t(3232)\t(2093)\t(10671)\nFinancial expense on non-current financial debt\t(554)\t(512)\t(431)\t(299)\t(189)\t(174)\t(2159)\nInterest differential on swaps\t118\t211\t100\t62\t37\t(7)\t521\nNet amount\t4192\t(3293)\t(3989)\t(3561)\t(3384)\t(2274)\t(12309)\n", "q10k_tbl_298": "As of December 31\t\t\t\n(M€)\t\t\t\nASSETS/(LIABILITIES)\t2010\t2009\t2008\nAccounts payable\t(18450)\t(15383)\t(14815)\nOther operating liabilities\t(3574)\t(4706)\t(4297)\nincluding financial instruments related to commodity contracts\t(559)\t(923)\t(1033)\nAccounts receivable net\t18159\t15719\t15287\nOther operating receivables\t4407\t5145\t6208\nincluding financial instruments related to commodity contracts\t499\t1029\t1664\nTotal\t542\t775\t2383\n", "q10k_tbl_299": "As of December 31\t\t\t\n(M€)\t\t\t\nASSETS/(LIABILITIES)\t2010\t2009\t2008\nLoans to equity affiliates (Note 12)\t2383\t2367\t2005\nLoans and advances (Note 14)\t1596\t1284\t1403\nHedging instruments of non-current financial debt (Note 20)\t1870\t1025\t892\nAccounts receivable (Note 16)\t18159\t15719\t15287\nOther operating receivables (Note 16)\t4407\t5145\t6208\nCurrent financial assets (Note 20)\t1205\t311\t187\nCash and cash equivalents (Note 27)\t14489\t11662\t12321\nTotal\t44109\t37513\t38303\n", "q10k_tbl_300": "0\tIn the United States investigations into certain commercial practices of some subsidiaries of the Arkema group have been closed since 2007; no charges have been brought against Arkema. Civil liability lawsuits for which TOTAL S.A. has been named as the parent company are about to be closed and are not expected to have a significant impact on the Group's financial position.\n0\tIn Europe since May 2006 the European Commission has fined companies of the Group in its configuration prior to the spin-off an overall amount of €385.47 million of which Elf Aquitaine and/or TOTAL S.A. and their subsidiaries were held jointly liable for €280.17 million Elf Aquitaine being personally fined €23.6 million for deterrence. These fines are entirely settled as of today.\n", "q10k_tbl_301": "0\tTOTAL is acquiring 19.2% of Suncor's interest in the Fort Hills project. Taking into account the acquisition of UTS finalized in September 2010 TOTAL will have an overall 39.2% interest in Fort Hills. Suncor as operator will hold 40.8%;\n0\tSuncor is acquiring 36.75% of TOTAL's interest in the Joslyn project. TOTAL as operator will retain a 38.25% interest in the project;\n0\tTOTAL is also acquiring a 49% stake in the Suncor-operated Voyageur upgrader project;\n0\tAs a result of the terms of these transactions and the related net balancing of the portfolio in particular to contribute to the past costs of the Voyageur project TOTAL will pay Suncor CAD 1751 million with a value date of January 1st 2011.\n", "q10k_tbl_302": "Proved developed and undeveloped reserves\tConsolidated subsidiaries\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million barrels of oil equivalent)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nBalance as of December 31 2007\t1900\t3516\t737\t474\t1224\t7851\nRevisions of previous estimates\t41\t374\t50\t106\t144\t715\nExtensions discoveries and other\t82\t110\t0\t0\t19\t211\nAcquisitions of reserves in place\t17\t0\t0\t0\t0\t17\nSales of reserves in place\t0\t(74)\t0\t0\t(46)\t(120)\nProduction for the year\t(225)\t(280)\t(55)\t(50)\t(99)\t(709)\nBalance as of December 31 2008\t1815\t3646\t732\t530\t1242\t7965\nRevisions of previous estimates\t46\t76\t14\t(7)\t25\t154\nExtensions discoveries and other\t18\t53\t284\t76\t0\t431\nAcquisitions of reserves in place\t12\t0\t130\t0\t0\t142\nSales of reserves in place\t(2)\t(43)\t(14)\t0\t0\t(59)\nProduction for the year\t(224)\t(266)\t(56)\t(55)\t(101)\t(702)\nBalance as of December 31 2009\t1665\t3466\t1090\t544\t1166\t7931\nRevisions of previous estimates\t92\t200\t82\t(10)\t1\t365\nExtensions discoveries and other\t182\t0\t18\t96\t30\t326\nAcquisitions of reserves in place\t23\t0\t425\t0\t9\t457\nSales of reserves in place\t(45)\t(26)\t(5)\t0\t(8)\t(84)\nProduction for the year\t(211)\t(269)\t(70)\t(56)\t(99)\t(705)\nBalance as of December 31 2010\t1706\t3371\t1540\t574\t1099\t8290\nMinority interest in proved developed and undeveloped reserves as of\t\t\t\t\t\t\nDecember 31 2008\t27\t100\t0\t0\t0\t127\nDecember 31 2009\t26\t98\t0\t0\t0\t124\nDecember 31 2010\t26\t100\t0\t0\t0\t126\n", "q10k_tbl_303": "Proved developed and undeveloped reserves\tEquity & non-consolidated affiliates\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million barrels of oil equivalent)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nBalance as of December 31 2007\t0\t69\t554\t1975\t0\t2598\nRevisions of previous estimates\t0\t22\t0\t(2)\t0\t20\nExtensions discoveries and other\t0\t14\t0\t3\t0\t17\nAcquisitions of reserves in place\t0\t0\t6\t0\t0\t6\nSales of reserves in place\t0\t0\t0\t0\t0\t0\nProduction for the year\t0\t(7)\t(33)\t(108)\t0\t(148)\nBalance as of December 31 2008\t0\t98\t527\t1868\t0\t2493\nRevisions of previous estimates\t0\t10\t(7)\t51\t0\t54\nExtensions discoveries and other\t0\t0\t0\t136\t0\t136\nAcquisitions of reserves in place\t0\t0\t0\t0\t0\t0\nSales of reserves in place\t0\t0\t0\t0\t0\t0\nProduction for the year\t0\t(8)\t(18)\t(105)\t0\t(131)\nBalance as of December 31 2009\t0\t100\t502\t1950\t0\t2552\nRevisions of previous estimates\t0\t14\t4\t(2)\t0\t16\nExtensions discoveries and other\t0\t0\t0\t0\t0\t0\nAcquisitions of reserves in place\t0\t0\t0\t0\t0\t0\nSales of reserves in place\t0\t0\t0\t0\t0\t0\nProduction for the year\t0\t(7)\t(20)\t(136)\t0\t(163)\nBalance as of December 31 2010\t0\t107\t486\t1812\t0\t2405\n", "q10k_tbl_304": "\tConsolidated subsidiaries and equity & non-consolidated affiliates\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million barrels of oil equivalent)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nAs of December 31 2008\t\t\t\t\t\t\nProved developed and undeveloped reserves\t1815\t3744\t1259\t2398\t1242\t10458\nConsolidated subsidiaries\t1815\t3646\t732\t530\t1242\t7965\nEquity and non-consolidated affiliates\t0\t98\t527\t1868\t0\t2493\nProved developed reserves\t1252\t1801\t515\t1194\t481\t5243\nConsolidated subsidiaries\t1252\t1754\t381\t504\t481\t4372\nEquity and non-consolidated affiliates\t0\t47\t134\t690\t0\t871\nProved undeveloped reserves\t563\t1943\t744\t1204\t761\t5215\nConsolidated subsidiaries\t563\t1892\t351\t26\t761\t3593\nEquity and non-consolidated affiliates\t0\t51\t393\t1178\t0\t1622\nAs of December 31 2009\t\t\t\t\t\t\nProved developed and undeveloped reserves\t1665\t3566\t1592\t2494\t1166\t10483\nConsolidated subsidiaries\t1665\t3466\t1090\t544\t1166\t7931\nEquity and non-consolidated affiliates\t0\t100\t502\t1950\t0\t2552\nProved developed reserves\t1096\t1775\t631\t1918\t415\t5835\nConsolidated subsidiaries\t1096\t1745\t503\t482\t415\t4241\nEquity and non-consolidated affiliates\t0\t30\t128\t1436\t0\t1594\nProved undeveloped reserves\t569\t1791\t961\t576\t751\t4648\nConsolidated subsidiaries\t569\t1721\t587\t62\t751\t3690\nEquity and non-consolidated affiliates\t0\t70\t374\t514\t0\t958\nAs of December 31 2010\t\t\t\t\t\t\nProved developed and undeveloped reserves\t1706\t3478\t2026\t2386\t1099\t10695\nConsolidated subsidiaries\t1706\t3371\t1540\t574\t1099\t8290\nEquity and non-consolidated affiliates\t0\t107\t486\t1812\t0\t2405\nProved developed reserves\t962\t1692\t638\t2055\t361\t5708\nConsolidated subsidiaries\t962\t1666\t505\t427\t361\t3921\nEquity and non-consolidated affiliates\t0\t26\t133\t1628\t0\t1787\nProved undeveloped reserves\t744\t1786\t1388\t331\t738\t4987\nConsolidated subsidiaries\t744\t1705\t1035\t147\t738\t4369\nEquity and non-consolidated affiliates\t0\t81\t353\t184\t0\t618\n", "q10k_tbl_305": "Proved developed and undeveloped reserves\tConsolidated subsidiaries\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million barrels)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nBalance as of December 31 2007\t880\t2498\t285\t203\t530\t4396\nRevisions of previous estimates\t15\t297\t(17)\t54\t64\t413\nExtensions discoveries and other\t12\t107\t0\t0\t3\t122\nAcquisitions of reserves in place\t2\t0\t0\t0\t0\t2\nSales of reserves in place\t0\t(74)\t0\t0\t(43)\t(117)\nProduction for the year\t(111)\t(231)\t(16)\t(32)\t(16)\t(406)\nBalance as of December 31 2008\t798\t2597\t252\t225\t538\t4410\nRevisions of previous estimates\t34\t92\t(170)\t(4)\t51\t3\nExtensions discoveries and other\t8\t38\t22\t1\t0\t69\nAcquisitions of reserves in place\t1\t0\t0\t0\t0\t1\nSales of reserves in place\t0\t(44)\t(1)\t0\t0\t(45)\nProduction for the year\t(108)\t(223)\t(15)\t(34)\t(17)\t(397)\nBalance as of December 31 2009\t733\t2460\t88\t188\t572\t4041\nRevisions of previous estimates\t46\t131\t7\t(2)\t0\t182\nExtensions discoveries and other\t146\t0\t2\t82\t4\t234\nAcquisitions of reserves in place\t2\t0\t0\t0\t0\t2\nSales of reserves in place\t(37)\t(23)\t(2)\t0\t(7)\t(69)\nProduction for the year\t(98)\t(218)\t(16)\t(29)\t(15)\t(376)\nBalance as of December 31 2010\t792\t2350\t79\t239\t554\t4014\nMinority interest in proved developed and undeveloped reserves as of\t\t\t\t\t\t\nDecember 31 2008\t12\t89\t0\t0\t0\t101\nDecember 31 2009\t12\t88\t0\t0\t0\t100\nDecember 31 2010\t11\t89\t0\t0\t0\t100\n", "q10k_tbl_306": "Proved developed and undeveloped reserves\tEquity & non-consolidated affiliates\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million barrels)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nBalance as of December 31 2007\t0\t43\t533\t806\t0\t1382\nRevisions of previous estimates\t0\t22\t1\t(2)\t0\t21\nExtensions discoveries and other\t0\t0\t0\t3\t0\t3\nAcquisitions of reserves in place\t0\t0\t6\t0\t0\t6\nSales of reserves in place\t0\t0\t0\t0\t0\t0\nProduction for the year\t0\t(7)\t(32)\t(88)\t0\t(127)\nBalance as of December 31 2008\t0\t58\t508\t719\t0\t1285\nRevisions of previous estimates\t0\t(14)\t(5)\t(15)\t0\t(34)\nExtensions discoveries and other\t0\t0\t0\t136\t0\t136\nAcquisitions of reserves in place\t0\t0\t0\t0\t0\t0\nSales of reserves in place\t0\t0\t0\t0\t0\t0\nProduction for the year\t0\t(7)\t(18)\t(79)\t0\t(104)\nBalance as of December 31 2009\t0\t37\t485\t761\t0\t1283\nRevisions of previous estimates\t0\t4\t4\t3\t0\t11\nExtensions discoveries and other\t0\t0\t0\t0\t0\t0\nAcquisitions of reserves in place\t0\t0\t0\t0\t0\t0\nSales of reserves in place\t0\t0\t0\t0\t0\t0\nProduction for the year\t0\t(7)\t(19)\t(84)\t0\t(110)\nBalance as of December 31 2010\t0\t34\t470\t680\t0\t1184\n", "q10k_tbl_307": "\tConsolidated subsidiaries and equity & non-consolidated affiliates\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million barrels)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nAs of December 31 2008\t\t\t\t\t\t\nProved developed and undeveloped reserves\t798\t2655\t760\t944\t538\t5695\nConsolidated subsidiaries\t798\t2597\t252\t225\t538\t4410\nEquity and non-consolidated affiliates\t0\t58\t508\t719\t0\t1285\nProved developed reserves\t516\t1357\t183\t681\t65\t2802\nConsolidated subsidiaries\t516\t1313\t56\t201\t65\t2151\nEquity and non-consolidated affiliates\t0\t44\t127\t480\t0\t651\nProved undeveloped reserves\t282\t1298\t577\t263\t473\t2893\nConsolidated subsidiaries\t282\t1284\t196\t24\t473\t2259\nEquity and non-consolidated affiliates\t0\t14\t381\t239\t0\t634\nAs of December 31 2009\t\t\t\t\t\t\nProved developed and undeveloped reserves\t733\t2497\t573\t949\t572\t5324\nConsolidated subsidiaries\t733\t2460\t88\t188\t572\t4041\nEquity and non-consolidated affiliates\t0\t37\t485\t761\t0\t1283\nProved developed reserves\t457\t1331\t187\t728\t65\t2768\nConsolidated subsidiaries\t457\t1303\t66\t174\t65\t2065\nEquity and non-consolidated affiliates\t0\t28\t121\t554\t0\t703\nProved undeveloped reserves\t276\t1166\t386\t221\t507\t2556\nConsolidated subsidiaries\t276\t1157\t22\t14\t507\t1976\nEquity and non-consolidated affiliates\t0\t9\t364\t207\t0\t580\nAs of December 31 2010\t\t\t\t\t\t\nProved developed and undeveloped reserves\t792\t2384\t549\t919\t554\t5198\nConsolidated subsidiaries\t792\t2350\t79\t239\t554\t4014\nEquity and non-consolidated affiliates\t0\t34\t470\t680\t0\t1184\nProved developed reserves\t394\t1250\t180\t662\t58\t2544\nConsolidated subsidiaries\t394\t1226\t53\t151\t58\t1882\nEquity and non-consolidated affiliates\t0\t24\t127\t511\t0\t662\nProved undeveloped reserves\t398\t1134\t369\t257\t496\t2654\nConsolidated subsidiaries\t398\t1124\t26\t88\t496\t2132\nEquity and non-consolidated affiliates\t0\t10\t343\t169\t0\t522\n", "q10k_tbl_308": "Proved developed and undeveloped reserves\tConsolidated subsidiaries\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million barrels)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nBalance as of December 31 2008\t0\t0\t0\t0\t0\t0\nRevisions of previous estimates\t0\t0\t176\t0\t0\t176\nExtensions discoveries and other\t0\t0\t192\t0\t0\t192\nAcquisitions of reserves in place\t0\t0\t0\t0\t0\t0\nSales of reserves in place\t0\t0\t0\t0\t0\t0\nProduction for the year\t0\t0\t(3)\t0\t0\t(3)\nBalance as of December 31 2009\t0\t0\t365\t0\t0\t365\nRevisions of previous estimates\t0\t0\t3\t0\t0\t3\nExtensions discoveries and other\t0\t0\t0\t0\t0\t0\nAcquisitions of reserves in place\t0\t0\t425\t0\t0\t425\nSales of reserves in place\t0\t0\t0\t0\t0\t0\nProduction for the year\t0\t0\t(4)\t0\t0\t(4)\nBalance as of December 31 2010\t0\t0\t789\t0\t0\t789\nProved developed reserves as of\t\t\t\t\t\t\nDecember 31 2009\t0\t0\t19\t0\t0\t19\nDecember 31 2010\t0\t0\t18\t0\t0\t18\nProved undeveloped reserves as of\t\t\t\t\t\t\nDecember 31 2009\t0\t0\t346\t0\t0\t346\nDecember 31 2010\t0\t0\t771\t0\t0\t771\n", "q10k_tbl_309": "Proved developed and undeveloped reserves\tConsolidated subsidiaries\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in billion cubic feet)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nBalance as of December 31 2007\t5531\t5371\t2564\t1572\t4045\t19083\nRevisions of previous estimates\t145\t381\t366\t300\t458\t1650\nExtensions discoveries and other\t377\t17\t0\t0\t90\t484\nAcquisitions of reserves in place\t76\t0\t0\t0\t0\t76\nSales of reserves in place\t0\t0\t0\t0\t(15)\t(15)\nProduction for the year\t(622)\t(240)\t(216)\t(103)\t(480)\t(1661)\nBalance as of December 31 2008\t5507\t5529\t2714\t1769\t4098\t19617\nRevisions of previous estimates\t73\t(127)\t25\t(18)\t(165)\t(212)\nExtensions discoveries and other\t55\t61\t382\t399\t0\t897\nAcquisitions of reserves in place\t58\t0\t752\t0\t0\t810\nSales of reserves in place\t(13)\t0\t(64)\t0\t0\t(77)\nProduction for the year\t(633)\t(217)\t(212)\t(122)\t(467)\t(1651)\nBalance as of December 31 2009\t5047\t5246\t3597\t2028\t3466\t19384\nRevisions of previous estimates\t271\t346\t415\t(80)\t15\t967\nExtensions discoveries and other\t193\t0\t88\t70\t138\t489\nAcquisitions of reserves in place\t111\t0\t0\t0\t51\t162\nSales of reserves in place\t(43)\t(20)\t(16)\t0\t(4)\t(83)\nProduction for the year\t(617)\t(258)\t(278)\t(151)\t(472)\t(1776)\nBalance as of December 31 2010\t4962\t5314\t3806\t1867\t3194\t19143\nMinority interest in proved developed and undeveloped reserves as of\t\t\t\t\t\t\nDecember 31 2008\t75\t64\t0\t0\t0\t139\nDecember 31 2009\t73\t60\t0\t0\t0\t133\nDecember 31 2010\t83\t67\t0\t0\t0\t150\n", "q10k_tbl_310": "Proved developed and undeveloped reserves\tEquity & non-consolidated affiliates\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in billion cubic feet)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nBalance as of December 31 2007\t0\t140\t125\t6382\t0\t6647\nRevisions of previous estimates\t0\t0\t(13)\t0\t0\t(13)\nExtensions discoveries and other\t0\t76\t0\t0\t0\t76\nAcquisitions of reserves in place\t0\t0\t0\t0\t0\t0\nSales of reserves in place\t0\t0\t0\t0\t0\t0\nProduction for the year\t0\t(1)\t(2)\t(106)\t0\t(109)\nBalance as of December 31 2008\t0\t215\t110\t6276\t0\t6601\nRevisions of previous estimates\t0\t127\t(13)\t363\t0\t477\nExtensions discoveries and other\t0\t0\t0\t0\t0\t0\nAcquisitions of reserves in place\t0\t0\t0\t0\t0\t0\nSales of reserves in place\t0\t0\t0\t0\t0\t0\nProduction for the year\t0\t(1)\t(2)\t(141)\t0\t(144)\nBalance as of December 31 2009\t0\t341\t95\t6498\t0\t6934\nRevisions of previous estimates\t0\t50\t(2)\t(52)\t0\t(4)\nExtensions discoveries and other\t0\t0\t0\t0\t0\t0\nAcquisitions of reserves in place\t0\t0\t0\t0\t0\t0\nSales of reserves in place\t0\t0\t0\t0\t0\t0\nProduction for the year\t0\t(1)\t(2)\t(282)\t0\t(285)\nBalance as of December 31 2010\t0\t390\t91\t6164\t0\t6645\n", "q10k_tbl_311": "\tConsolidated subsidiaries and equity & non-consolidated affiliates\t\t\t\t\t\n(in billion cubic feet)\tEurope\tAfrica\tAmericas\tMiddle East\tAsia\tTotal\nAs of December 31 2008\t\t\t\t\t\t\nProved developed and undeveloped reserves\t5507\t5744\t2824\t8045\t4098\t26218\nConsolidated subsidiaries\t5507\t5529\t2714\t1769\t4098\t19617\nEquity and non-consolidated affiliates\t0\t215\t110\t6276\t0\t6601\nProved developed reserves\t3989\t2292\t1849\t2893\t2440\t13463\nConsolidated subsidiaries\t3989\t2280\t1807\t1766\t2440\t12282\nEquity and non-consolidated affiliates\t0\t12\t42\t1127\t0\t1181\nProved undeveloped reserves\t1518\t3452\t975\t5152\t1658\t12755\nConsolidated subsidiaries\t1518\t3249\t907\t3\t1658\t7335\nEquity and non-consolidated affiliates\t0\t203\t68\t5149\t0\t5420\nAs of December 31 2009\t\t\t\t\t\t\nProved developed and undeveloped reserves\t5047\t5587\t3692\t8526\t3466\t26318\nConsolidated subsidiaries\t5047\t5246\t3597\t2028\t3466\t19384\nEquity and non-consolidated affiliates\t0\t341\t95\t6498\t0\t6934\nProved developed reserves\t3463\t2272\t2388\t6606\t2059\t16788\nConsolidated subsidiaries\t3463\t2261\t2343\t1773\t2059\t11899\nEquity and non-consolidated affiliates\t0\t11\t45\t4833\t0\t4889\nProved undeveloped reserves\t1584\t3315\t1304\t1920\t1407\t9530\nConsolidated subsidiaries\t1584\t2985\t1254\t255\t1407\t7485\nEquity and non-consolidated affiliates\t0\t330\t50\t1665\t0\t2045\nAs of December 31 2010\t\t\t\t\t\t\nProved developed and undeveloped reserves\t4962\t5704\t3897\t8031\t3194\t25788\nConsolidated subsidiaries\t4962\t5314\t3806\t1867\t3194\t19143\nEquity and non-consolidated affiliates\t0\t390\t91\t6164\t0\t6645\nProved developed reserves\t3089\t2240\t2474\t7649\t1790\t17242\nConsolidated subsidiaries\t3089\t2229\t2439\t1578\t1790\t11125\nEquity and non-consolidated affiliates\t0\t11\t35\t6071\t0\t6117\nProved undeveloped reserves\t1873\t3464\t1423\t382\t1404\t8546\nConsolidated subsidiaries\t1873\t3085\t1367\t289\t1404\t8018\nEquity and non-consolidated affiliates\t0\t379\t56\t93\t0\t528\n", "q10k_tbl_312": "\tConsolidated subsidiaries\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million euros)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\n2008\t\t\t\t\t\t\nNon-Group sales\t4521\t2930\t707\t1558\t2819\t12535\nGroup sales\t6310\t11425\t360\t409\t626\t19130\nTotal Revenues\t10831\t14355\t1067\t1967\t3445\t31665\nProduction costs\t(1280)\t(1055)\t(213)\t(249)\t(263)\t(3060)\nExploration expenses\t(185)\t(209)\t(130)\t(4)\t(236)\t(764)\nDepreciation depletion and amortization and valuation allowances\t(1266)\t(1195)\t(318)\t(364)\t(471)\t(3614)\nOther expenses(a)\t(260)\t(1214)\t(225)\t(357)\t(60)\t(2116)\nPre-tax income from producing activities\t7840\t10682\t181\t993\t2415\t22111\nIncome tax\t(5376)\t(7160)\t(109)\t(481)\t(1212)\t(14338)\nResults of oil and gas producing activities\t2464\t3522\t72\t512\t1203\t7773\n2009\t\t\t\t\t\t\nNon-Group sales\t2499\t1994\t583\t859\t1926\t7861\nGroup sales\t4728\t7423\t310\t556\t597\t13614\nTotal Revenues\t7227\t9417\t893\t1415\t2523\t21475\nProduction costs\t(1155)\t(1122)\t(193)\t(204)\t(243)\t(2917)\nExploration expenses\t(160)\t(265)\t(121)\t(81)\t(70)\t(697)\nDepreciation depletion and amortization and valuation allowances\t(1489)\t(1471)\t(262)\t(314)\t(613)\t(4149)\nOther expenses(a)\t(261)\t(895)\t(181)\t(170)\t(56)\t(1563)\nPre-tax income from producing activities\t4162\t5664\t136\t646\t1541\t12149\nIncome tax\t(2948)\t(3427)\t(103)\t(309)\t(747)\t(7534)\nResults of oil and gas producing activities\t1214\t2237\t33\t337\t794\t4615\n2010\t\t\t\t\t\t\nNon-Group sales\t2839\t2639\t628\t1038\t2540\t9684\nGroup sales\t5599\t9894\t540\t644\t683\t17360\nTotal Revenues\t8438\t12533\t1168\t1682\t3223\t27044\nProduction costs\t(1281)\t(1187)\t(222)\t(259)\t(279)\t(3228)\nExploration expenses\t(266)\t(275)\t(216)\t(8)\t(99)\t(864)\nDepreciation depletion and amortization and valuation allowances\t(1404)\t(1848)\t(368)\t(264)\t(830)\t(4714)\nOther expenses(a)\t(299)\t(1014)\t(218)\t(241)\t(72)\t(1844)\nPre-tax income from producing activities\t5188\t8209\t144\t910\t1943\t16394\nIncome tax\t(3237)\t(5068)\t(83)\t(402)\t(950)\t(9740)\nResults of oil and gas producing activities\t1951\t3141\t61\t508\t993\t6654\n", "q10k_tbl_313": "\tEquity affiliates\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million euros)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nGroup's share of results of oil and gas producing activities\t\t\t\t\t\t\n2008\t0\t49\t245\t287\t0\t581\n2009\t\t\t\t\t\t\nNon-Group sales\t0\t203\t528\t231\t0\t962\nGroup sales\t0\t0\t0\t3382\t0\t3382\nTotal Revenues\t0\t203\t528\t3613\t0\t4344\nProduction costs\t0\t(31)\t(41)\t(271)\t0\t(343)\nExploration expenses\t0\t0\t(17)\t0\t0\t(17)\nDepreciation depletion and amortization and valuation allowances\t0\t(42)\t(73)\t(247)\t0\t(362)\nOther expenses\t0\t(9)\t(205)\t(2800)\t0\t(3014)\nPre-tax income from producing activities\t0\t121\t192\t295\t0\t608\nIncome tax\t0\t(93)\t(74)\t(101)\t0\t(268)\nResults of oil and gas producing activities\t0\t28\t118\t194\t0\t340\n2010\t\t\t\t\t\t\nNon-Group sales\t0\t148\t120\t596\t0\t864\nGroup sales\t0\t3\t565\t4646\t0\t5214\nTotal Revenues\t0\t151\t685\t5242\t0\t6078\nProduction costs\t0\t(44)\t(53)\t(195)\t(1)\t(293)\nExploration expenses\t0\t(7)\t(23)\t0\t0\t(30)\nDepreciation depletion and amortization and valuation allowances\t0\t(44)\t(89)\t(259)\t0\t(392)\nOther expenses\t0\t0\t(268)\t(4034)\t0\t(4302)\nPre-tax income from producing activities\t0\t56\t252\t754\t(1)\t1061\nIncome tax\t0\t0\t(44)\t(142)\t0\t(186)\nResults of oil and gas producing activities\t0\t56\t208\t612\t(1)\t875\n", "q10k_tbl_314": "\tConsolidated subsidiaries\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million euros)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\n2008\t\t\t\t\t\t\nProved property acquisition\t269\t78\t0\t8\t18\t373\nUnproved property acquisition\t24\t143\t22\t5\t3\t197\nExploration costs\t228\t493\t155\t11\t312\t1199\nDevelopment costs(a)\t2035\t3121\t408\t281\t1596\t7441\nTotal cost incurred\t2556\t3835\t585\t305\t1929\t9210\n2009\t\t\t\t\t\t\nProved property acquisition\t71\t45\t1551\t105\t0\t1772\nUnproved property acquisition\t26\t8\t403\t0\t21\t458\nExploration costs\t284\t475\t222\t87\t123\t1191\nDevelopment costs(a)\t1658\t3288\t618\t250\t1852\t7666\nTotal cost incurred\t2039\t3816\t2794\t442\t1996\t11087\n2010\t\t\t\t\t\t\nProved property acquisition\t162\t137\t26\t139\t21\t485\nUnproved property acquisition\t5\t124\t1186\t8\t619\t1942\nExploration costs\t361\t407\t276\t17\t250\t1311\nDevelopment costs(a)\t1565\t3105\t718\t247\t2007\t7642\nTotal cost incurred\t2093\t3773\t2206\t411\t2897\t11380\n", "q10k_tbl_315": "Group's share of costs of property acquisition exploration and development\tEquity affiliates\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million euros)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\n2008\t0\t360\t85\t527\t0\t972\n2009\t\t\t\t\t\t\nProved property acquisition\t0\t0\t0\t0\t0\t0\nUnproved property acquisition\t0\t0\t0\t0\t0\t0\nExploration costs\t0\t0\t22\t3\t0\t25\nDevelopment costs(a)\t0\t28\t93\t293\t23\t437\nTotal cost incurred\t0\t28\t115\t296\t23\t462\n2010\t\t\t\t\t\t\nProved property acquisition\t0\t0\t0\t0\t0\t0\nUnproved property acquisition\t0\t0\t0\t0\t0\t0\nExploration costs\t0\t4\t30\t4\t0\t38\nDevelopment costs(a)\t0\t20\t99\t476\t73\t668\nTotal cost incurred\t0\t24\t129\t480\t73\t706\n", "q10k_tbl_316": "\tConsolidated subsidiaries\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million euros)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nAs of December 31 2008\t\t\t\t\t\t\nProved properties\t26030\t25136\t4508\t4824\t8836\t69334\nUnproved properties\t132\t1145\t204\t25\t410\t1916\nTotal capitalized costs\t26162\t26281\t4712\t4849\t9246\t71250\nAccumulated depreciation depletion and amortization\t(18382)\t(12339)\t(2051)\t(3420)\t(2598)\t(38790)\nNet capitalized costs\t7780\t13942\t2661\t1429\t6648\t32460\nAs of December 31 2009\t\t\t\t\t\t\nProved properties\t30613\t27557\t7123\t5148\t10102\t80543\nUnproved properties\t337\t1138\t839\t30\t555\t2899\nTotal capitalized costs\t30950\t28695\t7962\t5178\t10657\t83442\nAccumulated depreciation depletion and amortization\t(21870)\t(13510)\t(2214)\t(3325)\t(3085)\t(44004)\nNet capitalized costs\t9080\t15185\t5748\t1853\t7572\t39438\nAs of December 31 2010\t\t\t\t\t\t\nProved properties\t31735\t32494\t7588\t5715\t12750\t90282\nUnproved properties\t402\t1458\t2142\t49\t1433\t5484\nTotal capitalized costs\t32137\t33952\t9730\t5764\t14183\t95766\nAccumulated depreciation depletion and amortization\t(23006)\t(16716)\t(2302)\t(3849)\t(4092)\t(49965)\nNet capitalized costs\t9131\t17236\t7428\t1915\t10091\t45801\n", "q10k_tbl_317": "Group's share of net capitalized costs\tEquity affiliates\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million euros)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nAs of December 31 2008\t0\t403\t288\t638\t0\t1329\nAs of December 31 2009\t\t\t\t\t\t\nProved properties\t0\t610\t726\t2404\t0\t3740\nUnproved properties\t0\t0\t135\t0\t62\t197\nTotal capitalized costs\t0\t610\t861\t2404\t62\t3937\nAccumulated depreciation depletion and amortization\t0\t(387)\t(171)\t(1723)\t0\t(2281)\nNet capitalized costs\t0\t223\t690\t681\t62\t1656\nAs of December 31 2010\t\t\t\t\t\t\nProved properties\t0\t639\t887\t3110\t0\t4636\nUnproved properties\t0\t25\t168\t0\t138\t331\nTotal capitalized costs\t0\t664\t1055\t3110\t138\t4967\nAccumulated depreciation depletion and amortization\t0\t(462)\t(307)\t(2029)\t0\t(2798)\nNet capitalized costs\t0\t202\t748\t1081\t138\t2169\n", "q10k_tbl_318": "\tConsolidated subsidiaries\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million euros)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nAs of December 31 2008\t\t\t\t\t\t\nFuture cash inflows\t42749\t67761\t7963\t7047\t19745\t145265\nFuture production costs\t(8593)\t(15372)\t(4040)\t(1942)\t(5224)\t(35171)\nFuture development costs\t(10423)\t(21594)\t(1863)\t(733)\t(7497)\t(42110)\nFuture income taxes\t(15651)\t(14571)\t(367)\t(1577)\t(2545)\t(34711)\nFuture net cash flows after income taxes\t8082\t16224\t1693\t2795\t4479\t33273\nDiscount at 10%\t(3645)\t(8144)\t(715)\t(1333)\t(3450)\t(17287)\nStandardized measure of discounted future net cash flows\t4437\t8080\t978\t1462\t1029\t15986\nAs of December 31 2009\t\t\t\t\t\t\nFuture cash inflows\t50580\t107679\t18804\t9013\t32004\t218080\nFuture production costs\t(11373)\t(23253)\t(8286)\t(2831)\t(6996)\t(52739)\nFuture development costs\t(12795)\t(21375)\t(5728)\t(698)\t(6572)\t(47168)\nFuture income taxes\t(17126)\t(36286)\t(1293)\t(2041)\t(5325)\t(62071)\nFuture net cash flows after income taxes\t9286\t26765\t3497\t3443\t13111\t56102\nDiscount at 10%\t(3939)\t(13882)\t(2696)\t(1558)\t(8225)\t(30300)\nStandardized measure of discounted future net cash flows\t5347\t12883\t801\t1885\t4886\t25802\nAs of December 31 2010\t\t\t\t\t\t\nFuture cash inflows\t65644\t142085\t42378\t14777\t41075\t305959\nFuture production costs\t(16143)\t(29479)\t(19477)\t(4110)\t(6476)\t(75685)\nFuture development costs\t(18744)\t(25587)\t(8317)\t(3788)\t(8334)\t(64770)\nFuture income taxes\t(20571)\t(51390)\t(3217)\t(2541)\t(7281)\t(85000)\nFuture net cash flows after income taxes\t10186\t35629\t11367\t4338\t18984\t80504\nDiscount at 10%\t(5182)\t(16722)\t(8667)\t(2106)\t(11794)\t(44471)\nStandardized measure of discounted future net cash flows\t5004\t18907\t2700\t2232\t7190\t36033\nMinority interests in future net cash flows as of\t\t\t\t\t\t\nDecember 31 2008\t217\t(50)\t0\t0\t0\t167\nDecember 31 2009\t212\t60\t0\t0\t0\t272\nAs of December 31 2010\t273\t344\t0\t0\t0\t617\n", "q10k_tbl_319": "\tEquity affiliates\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n(in million euros)\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\nGroup's share of future net cash flows\t\t\t\t\t\t\nAs of December 31 2008\t0\t418\t608\t4275\t0\t5301\nAs of December 31 2009\t\t\t\t\t\t\nFuture cash inflows\t0\t1432\t16750\t48486\t0\t66668\nFuture production costs\t0\t(624)\t(6993)\t(30739)\t0\t(38356)\nFuture development costs\t0\t(26)\t(1924)\t(3891)\t0\t(5841)\nFuture income taxes\t0\t(245)\t(3650)\t(1843)\t0\t(5738)\nFuture net cash flows after income taxes\t0\t537\t4183\t12013\t0\t16733\nDiscount at 10%\t0\t(239)\t(2816)\t(6383)\t0\t(9438)\nStandardized measure of discounted future net cash flows\t0\t298\t1367\t5630\t0\t7295\nAs of December 31 2010\t\t\t\t\t\t\nFuture cash inflows\t0\t1814\t22293\t59472\t0\t83579\nFuture production costs\t0\t(765)\t(8666)\t(40085)\t0\t(49516)\nFuture development costs\t0\t(26)\t(2020)\t(3006)\t0\t(5052)\nFuture income taxes\t0\t(349)\t(5503)\t(2390)\t0\t(8242)\nFuture net cash flows after income taxes\t0\t674\t6104\t13991\t0\t20769\nDiscount at 10%\t0\t(203)\t(3946)\t(7386)\t0\t(11535)\nStandardized measure of discounted future net cash flows\t0\t471\t2158\t6605\t0\t9234\n", "q10k_tbl_320": "(in million euros)\t2010\t2009\t2008\nConsolidated subsidiaries\t\t\t\nBeginning of year\t25802\t15986\t48464\nSales and transfers net of production costs\t(22297)\t(17266)\t(26109)\nNet change in sales and transfer prices and in production costs and other expenses\t30390\t35738\t(81358)\nExtensions discoveries and improved recovery\t716\t(267)\t556\nChanges in estimated future development costs\t(7245)\t(4847)\t(2227)\nPreviously estimated development costs incurred during the year\t7896\t7552\t6960\nRevisions of previous quantity estimates\t5523\t164\t2693\nAccretion of discount\t2580\t1599\t4846\nNet change in income taxes\t(6773)\t(12455)\t63611\nPurchases of reserves in place\t442\t230\t50\nSales of reserves in place\t(1001)\t(632)\t(1500)\nEnd of year\t36033\t25802\t15986\n", "q10k_tbl_321": "(in million euros)\t2010\t2009\nEquity affiliates\t\t\nBeginning of year\t7295\t5301\nSales and transfers net of production costs\t(1583)\t(987)\nNet change in sales and transfer prices and in production costs and other expenses\t2366\t2789\nExtensions discoveries and improved recovery\t0\t407\nChanges in estimated future development costs\t195\t(88)\nPreviously estimated development costs incurred during the year\t651\t854\nRevisions of previous quantity estimates\t308\t(790)\nAccretion of discount\t730\t530\nNet change in income taxes\t(728)\t(721)\nPurchases of reserves in place\t0\t0\nSales of reserves in place\t0\t0\nEnd of year\t9234\t7295\n", "q10k_tbl_322": "\tConsolidated subsidiaries\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\n2009\t\t\t\t\t\t\nNatural gas production available for sale (Mcf/d)(a)\t1643\t480\t545\t297\t1224\t4189\nProduction prices(b)\t\t\t\t\t\t\nOil (€/b)\t40.76\t40.77\t36.22\t39.94\t37.66\t40.38\nBitumen (€/b)\t0\t0\t23.17\t0\t0\t23.17\nNatural gas (€/kcf)\t4.81\t1.33\t1.56\t0.72\t4.47\t3.70\nProduction costs per unit of production (€/boe)(c)(d)\t\t\t\t\t\t\nTotal liquids and natural gas\t5.30\t4.35\t3.59\t3.86\t2.52\t4.30\nBitumen\t0\t0\t25.45\t0\t0\t25.45\n", "q10k_tbl_323": "\tEquity affiliates\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\n2009\t\t\t\t\t\t\nNatural gas production available for sale (Mcf/d)(a)\t0\t0\t0\t268\t0\t268\nProduction prices(b)\t\t\t\t\t\t\nOil (€/b)\t0\t42.98\t33.14\t43.98\t0\t42.18\nBitumen (€/b)\t0\t0\t0\t\t0\t0\nNatural gas (€/kcf)\t0\t0\t0\t3.53\t0\t3.53\nProduction costs per unit of production (€/boe)(c)\t\t\t\t\t\t\nTotal liquids and natural gas\t0\t4.21\t2.24\t2.81\t0\t2.81\nBitumen\t0\t0\t0\t0\t0\t0\n", "q10k_tbl_324": "\tConsolidated subsidiaries\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\n2010\t\t\t\t\t\t\nNatural gas production available for sale (Mcf/d)(a)\t1603\t608\t732\t375\t1234\t4552\nProduction prices(b)\t\t\t\t\t\t\nOil (€/b)\t55.70\t56.18\t45.28\t55.83\t52.33\t55.39\nBitumen (€/b)\t0\t0\t33.19\t0\t0\t33.19\nNatural gas (€/kcf)\t5.17\t1.55\t1.83\t0.63\t5.67\t3.94\nProduction costs per unit of production (€/boe)(c)\t\t\t\t\t\t\nTotal liquids and natural gas\t6.23\t4.53\t3.29\t4.82\t2.93\t4.72\nBitumen\t0\t0\t17.49\t0\t0\t17.49\n", "q10k_tbl_325": "\tEquity affiliates\t\t\t\t\t\n\t\t\t\tMiddle\t\t\n\tEurope\tAfrica\tAmericas\tEast\tAsia\tTotal\n2010\t\t\t\t\t\t\nNatural gas production available for sale (Mcf/d)(a)\t0\t0\t0\t650\t0\t650\nProduction prices(b)\t\t\t\t\t\t\nOil (€/b)\t0\t53.96\t43.81\t57.03\t0\t54.95\nBitumen (€/b)\t0\t0\t0\t0\t0\t0\nNatural gas (€/kcf)\t0\t0\t0\t2.30\t0\t2.30\nProduction costs per unit of production (€/boe)(c)\t\t\t\t\t\t\nTotal liquids and natural gas\t0\t6.31\t2.76\t1.54\t0\t1.91\nBitumen\t0\t0\t0\t0\t0\t0\n"}{"bs": "q10k_tbl_127", "is": "q10k_tbl_125", "cf": "q10k_tbl_127"}None
UNITED STATES SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D.C. 20549
Form 20-F
(Mark One)
o
REGISTRATION STATEMENT PURSUANT TO SECTION 12(b) OR 12(g) OF THE SECURITIES EXCHANGE ACT OF 1934
OR
x
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2010
OR
o
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
OR
o
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 American Depositary Shares
New York Stock Exchange* 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 issuers classes of capital or common stock as of the close of the period covered by the annual report.
2,349,640,931 Shares, par value 2.50 each, as of December 31, 2010
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes x No o
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 o No x
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 x No o
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 o No o
** 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 x
Accelerated filer o
Non-accelerated filer o
Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing:
U.S. GAAP o
International Financial Reporting Standards as issued by the International Accounting Standards Board x
Other o
If Other has been checked in response to the previous question, indicate by check mark which financial statement item the registrant has elected to follow. Item 17 o Item 18 o
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 o No x
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, 2010.
Statements Regarding Competitive Position
Unless otherwise indicated, statements made in Item 4. Information on the Company referring to TOTALs competitive position are based on the Companys estimates, and in some cases rely on a range of sources, including investment analysts reports, independent market studies and TOTALs 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 TOTALs business and operations and financial information relating to the fiscal year ended December 31, 2010. For more recent updates regarding TOTAL, you may read and copy any reports, statements or other information TOTAL files with the United States Securities and Exchange Commission (SEC). All of TOTALs SEC filings made after December 31, 2001, are available to the public at the SEC Web site at http://www.sec.gov and from certain commercial document retrieval services. See also Item 10. Additional Information Documents on Display.
Unless the context indicates otherwise, the following terms have the meanings shown below:
acreage
The total 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.
barrels
Barrels of crude oil, natural gas liquids (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 natural gas liquids (NGL).
Depositary
The Bank of New York Mellon.
DepositaryAgreement
The depositary agreement pursuant to which ADSs are issued, a copy of which is attached as Exhibit 1 to the registration statement on Form F-6 (Reg. No. 333-172005) filed with the SEC on February 1, 2011.
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 and natural gas liquids (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
NGL
Natural gas liquids consist of condensates and liquefied petroleum gas (LPG).
oil and gas
Generic term which includes all hydrocarbons (e.g., crude oil, natural gas liquids (NGL), bitumen and natural gas).
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).
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 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).
provedundeveloped 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 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).
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.
ERMI
ERMI is an 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.
turnarounds
Temporary shutdowns of facilities for maintenance, overhaul and upgrading.
= approximately 7.5 b of oil (assuming a specific gravity of 37° API)
1 t of LNG
= approximately 48 kcf of gas
1 Mt/y LNG
= approximately 131 Mcf/d
(a)
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 TOTALs natural gas reserves during the applicable periods, and is subject to change. The tabular conversion rate is applicable to TOTALs natural gas reserves on a group-wide basis.
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. TOTALs 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 TOTALs 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 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. Risk Factors, Item 4. Information on the Company Other Matters, Item 5. Operating and Financial Review and Prospects and Item 11. Quantitative and Qualitative Disclosures About Market Risk.
Average number outstanding of common shares 2.50 par value (shares undiluted)
2,234,829,043
2,230,599,211
2,234,856,551
2,255,294,231
2,293,063,190
Average number outstanding of common shares 2.50 par value (shares diluted)
2,244,494,576
2,237,292,199
2,246,658,542
2,274,384,984
2,312,304,652
(a)
See Consolidated Statement of Cash Flows included in the Consolidated Financial Statements.
(b)
Comparative cash flow information for 2006 includes Arkema, which was spun off on May 12, 2006.
(c)
Subject to approval by the shareholders meeting on May 13, 2011.
(d)
Estimated dividend in dollars includes the interim dividend of $1.542 paid in November 2010 and the proposed final dividend of 1.14, converted at a rate of $1.30/.
(e)
The number of common shares shown has been used to calculate per share amounts.
The ECB reference exchange rate on March 21, 2011, for the dollar against the euro was $1.42/.
(1) For the period 2006 2010, 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: 2006 1.26; 2007 1.38; 2008 1.47; 2009 1.40; and 2010 1.32.
global and regional economic and political developments in resource-producing regions, particularly in the Middle East, Africa and South America;
global and regional supply and demand;
the ability of the Organization of Petroleum Exporting Countries (OPEC) and other producing nations to influence global production levels and prices;
prices of alternative fuels which affect our realized prices under our long-term gas sales contracts;
governmental regulations and actions;
global economic and financial market conditions;
war or other conflicts;
cost and availability of new technology;
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 our facilities.
Substantial or extended declines in oil and natural gas prices would adversely affect our results of operations by reducing our profits. For the year 2011, we estimate that a decrease of $1.00 per barrel in the average annual price of Brent crude would have the effect of reducing our annual adjusted net operating income from the Upstream segment by approximately 0.13 billion (calculated with a base case exchange rate of $1.30 per 1.00). 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 reviews for impairment of the Groups oil and natural gas properties and could impact reserves. Such reviews would reflect managements view of long-term oil and natural gas prices and could result in a charge for impairment that could have a significant effect on our results of operations in the period in which it occurs. Lower oil and natural gas prices over prolonged periods may also reduce the economic viability of projects planned or in development, causing us to cancel or postpone capital expansion projects, and may reduce liquidity, thereby potentially decreasing our ability to finance capital expenditures. If we are unable to follow through with capital expansion projects, our opportunities for future revenue and profitability growth would be reduced, which could materially impact our financial condition.
We face foreign exchange risks that could adversely affect our results of operations.
Our business faces foreign exchange risks because a large percentage of our revenues and cash receipts are denominated in dollars, the international currency of petroleum sales, while a significant portion of our operating expenses and income taxes accrue in euros and other currencies. Movements between the dollar and euro or other currencies may adversely affect our business by negatively impacting our booked revenues and income, and may also result in significant translation adjustments that impact our shareholders equity.
Our long-term profitability depends on cost effective discovery and development of new reserves; if we are unsuccessful, our results of operations and financial condition would be materially and adversely affected.
A significant portion of our revenues and the majority of our operating income are derived from the sale of crude oil and natural gas which we extract from underground reserves discovered and developed as part of our Upstream business. In order for this business to continue to be profitable, we need to replace depleted reserves with new proved reserves. Furthermore, we need to accomplish such replacement in a manner that allows subsequent production to be economically viable. However, our ability to discover or acquire and develop new reserves successfully is uncertain and can be negatively affected by a number of factors, including:
unexpected drilling conditions, including pressure or irregularities in geological formations;
equipment failures or accidents;
our inability to develop new technologies that permit access to previously inaccessible fields;
compliance with unanticipated governmental requirements;
shortages or delays in the availability or delivery of appropriate equipment;
industrial action; and
problems with legal title.
Any of these factors could lead to cost overruns and impair our ability to make discoveries or complete a development project, or to make production economical. If we fail to discover and develop new reserves cost-effectively on an ongoing basis, our results of operations, including profits, and our financial condition, would be materially and adversely affected.
Our crude oil and natural gas reserve data are only estimates, and subsequent downward adjustments are possible. If actual production from such reserves is lower than current estimates indicate, our results of operations and financial condition would be negatively impacted.
Our proved reserves figures are estimates reflecting applicable reporting regulations as they may evolve. Proved reserves are those reserves which, by analysis of geosciences and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. Reserves are estimated by teams of qualified, experienced and trained earth scientists, 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 which are beyond our control and which could cause such estimates to be adjusted downward in the future, or cause our actual production to be lower than our 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 that we are entitled to under production sharing and risked service contracts;
changes in tax rules and other government regulations that make reserves no longer economically viable to exploit; and
the actual production performance of our reservoirs.
Our reserves estimates may therefore require substantial downward revisions to the extent our subjective judgments prove not to have been conservative enough based on the available geosciences and engineering data, or our assumptions regarding factors or variables that are beyond our control prove to be incorrect over time. Any downward adjustment would indicate lower future production amounts, which could adversely affect our results of operations, including profits as well as our financial condition.
We have significant production and reserves located in politically, economically and socially unstable areas, where the likelihood of material disruption of our operations is relatively high.
A significant portion of our oil and gas production occurs in unstable regions around the world, most significantly Africa, but also the Middle East, Asia-Pacific and South America. Approximately 32%, 22%, 10% and 8%, respectively, of our 2010 combined liquids and gas production came from these four regions. In recent years, a number of the countries in these regions have experienced varying degrees of one or more of the following: economic instability, political volatility, civil war, violent conflict and social unrest. In Africa, certain of the countries in which we have production have recently suffered from some of these conditions. The Middle East in general has recently suffered increased political volatility in connection with violent conflict and social unrest. A number of countries in South America where we have production and other facilities, including Argentina, Bolivia and Venezuela, have suffered from political or economic instability and social unrest and related problems. In Asia-Pacific, Indonesia has suffered some of these conditions. Any of these conditions alone or in combination could disrupt our operations in any of these regions, causing substantial declines in production. Furthermore, in addition to current production, we are 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 we have a number of 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 our production and operations in the future.
We are exposed to risks regarding the safety and security of our operations. In addition, while our insurance coverage is in line with industry practice, we are not insured against all possible risks.
TOTAL engages in a broad scope of activities, which include drilling, oil and gas production, processing, transportation, refining and petrochemical activities, storage and distribution of petroleum products, and production of base chemical and specialty products, and involve a wide range of operational risks. Among these risks are those of explosion, fire or leakage of toxic products, as well as environmental risks related to emissions and discharges into the air, water or soil and the management of waste. We also face risks, once production is discontinued, because our activities require environmental site remediation. 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 pipelines, maritime, river-maritime, rail, road), the volumes involved, and the sensitivity of the regions through which the transport passes (quality of infrastructure, population density, environmental considerations).
Certain branches or activities face specific additional risks. In Exploration & Production, we face risks related to the physical characteristics of our oil or gas fields. These include the risks of eruptions of crude oil or of natural gas, discovery of hydrocarbon pockets with abnormal pressure, crumbling of well openings, leaks that can harm the environment and risks of fire or explosion. These events may cause injury or death, damage or destroy crude oil or natural gas wells as well as equipment and other property, lead to a disruption of activity or cause environmental damage. In addition, since exploration and production activities may take place on sites that are ecologically sensitive (tropical forest, marine environment, etc.), each site requires a risk-based approach to avoid or minimize the impact on human health, flora and fauna, the ecosystem and biodiversity. TOTALs activities in the Chemicals segment and the Refining & Marketing division also entail additional health, safety and environmental risks related to the overall life cycle of the products manufactured, as well as raw materials used in the manufacturing process, such as catalysts, additives and monomer feedstocks. 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, and from recycling or disposing of materials and wastes at the end of their useful life.
If an event occurs leading to personal injury, death, property damage or discharge of hazardous materials into the environment, contractual terms may provide for indemnification obligations, either by TOTAL in favor of third-parties or by third-parties for TOTALs benefit. With respect to joint ventures operated by TOTAL, contractual terms generally provide that TOTAL assumes liability for damages caused by its gross negligence or willful misconduct. With respect to joint ventures in which TOTAL has an interest but that are operated by others, contractual terms generally provide that the operator assumes liability for damages caused by its gross negligence or willful misconduct. All other liabilities of any type of joint venture are generally assumed by the partners in proportion to their respective ownership interests. With respect to third party providers of goods and services, the amount and nature of liabilities assumed by the third party depends on the context and may be limited by contract. With respect to the Groups customers, TOTAL seeks to ensure that its products meet applicable specifications and that TOTAL abides by all applicable consumer protection laws.
To manage these risks, we maintain worldwide third-party liability insurance coverage for all of our subsidiaries. In addition, we also maintain insurance to protect us against the risk of damage to Group property and/or business disruption. Our insurance and risk management policies are described under Item 4. Other Matters Insurance and risk management. While we believe our insurance coverage is in line with industry practice and sufficient to cover normal risks in our operations, we are not insured against all possible risks. In the event of a major environmental disaster, for example, our liability may exceed the maximum coverage provided by our third-party liability insurance. The loss we could suffer in the event of such a disaster would depend on all the facts and circumstances 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 assurance,
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.
We are subject to stringent environmental, health and safety laws in numerous jurisdictions around the world and may incur material costs to comply with these laws and regulations.
Our workforce and the public are exposed to risks inherent to our operations that potentially could lead to injuries, loss of life or environmental damage and could result in regulatory action, legal liability and damage to our reputation.
We incur, and expect to continue to incur, substantial capital and operating expenditures to comply with increasingly complex laws and regulations covering the protection of the natural environment and the promotion of worker health and safety, including:
costs to prevent, control, eliminate or reduce certain types of air and water emissions, including those costs incurred in connection with government action to address climate change;
remedial measures related to environmental contamination or accidents at various sites, including those owned by third parties;
compensation of persons claiming damages caused by our activities or accidents; and
costs in connection with the decommissioning of drilling platforms and other facilities.
In addition, growing public concerns in the EU and globally that rising greenhouse gas emissions and climate change may significantly affect the environment and society could adversely affect our businesses, including by the addition of stricter regulations that increase our operating costs, affect product sales and reduce profitability.
If our established financial reserves prove inadequate, environmental costs could have a material effect on our results of operations and our financial position. Furthermore, in the countries where we operate or expect to operate in the near future, new laws and regulations, the imposition of tougher license requirements, increasingly strict enforcement or new interpretations of existing laws and regulations or the discovery of previously unknown contamination may also cause us to incur material costs resulting from actions taken to comply with such laws and regulations, including:
modifying operations;
installing pollution control equipment;
implementing additional safety measures; and
performing site clean-ups.
As a further result of any new laws and regulations or other factors, we may also have to curtail, modify or cease certain operations or implement temporary shutdowns of facilities, which could diminish our productivity and materially and adversely impact our results of operations, including profits.
Security threats require continuous assessment and response measures. Acts of terrorism against our plants and offices, pipelines, transportation or computer systems could severely disrupt businesses and operations and could cause harm to people.
Our operations throughout the developing world are subject to intervention by various governments, which could have an adverse effect on our results of operations.
We have significant exploration and production, and in some cases refining, marketing or chemicals operations, in developing countries whose governmental and regulatory framework is subject to unexpected change and where the enforcement of contractual rights is uncertain. In addition, our exploration and production activity in such countries is 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, we have seen governments and state-owned enterprises exercising greater authority and imposing more stringent conditions on companies pursuing exploration and production activities in their respective countries, increasing the costs and uncertainties of our business operations, which is a trend we expect 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;
nationalization or expropriation of our assets;
unilateral cancellation or modification of our license or contract rights;
increases in taxes and royalties, including retroactive claims;
the establishment of production and export limits;
the renegotiation of contracts;
payment delays; and
currency exchange restrictions or currency devaluation.
Imposition of any of these factors by a host government in a developing country where we have substantial operations, including exploration, could cause us to incur material costs or cause our production to decrease, potentially having a material adverse effect on our results of operations, including profits.
We have activities in certain countries which are subject to U.S. and EU sanctions and our activities in Iran could lead to sanctions under relevant U.S. and EU legislation.
We currently have investments in Iran and, to a lesser extent, Syria, Myanmar, Sudan and Cuba. U.S. legislation and regulations currently impose economic sanctions on these countries.
In 1996, the United States adopted legislation implementing sanctions against non-U.S. companies doing business in Iran and Libya (the Iran and Libya Sanctions Act, referred to as ILSA), which in 2006 was amended to concern only business in Iran (then renamed the Iran Sanctions Act, referred to as ISA).
Pursuant to this statute, the President of the United States is authorized to initiate an investigation into the activities of non-U.S. companies in Iran and the possible imposition of sanctions (from a list that includes denial of financing by the U.S. Export-Import Bank, limitations on the amount of loans or credits available from U.S. financial institutions and prohibition of U.S. federal procurements from sanctioned persons) against persons found, in particular, to have knowingly made investments of $20 million or more in any 12-month period in the petroleum sector in Iran. In May 1998, the U.S. government waived the application of sanctions for TOTALs investment in the South Pars gas field. This waiver, which has not been modified since it was granted, does not address TOTALs other activities in Iran, although TOTAL has not been notified of any related sanctions.
In November 1996, the Council of the European Union adopted regulations which prohibit TOTAL from complying with any requirement or prohibition based on or resulting directly or indirectly from certain enumerated legislation, including ILSA (now ISA). It also prohibits TOTAL from having its waiver for South Pars extended to other activities.
In each of the years since the passage of ILSA and until 2007, TOTAL made investments in Iran in excess of $20 million (excluding the investments made as part of the development of South Pars). Since 2008, TOTALs position has consisted essentially in 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. In 2010, TOTALs production in Iran represented less than 0.1% of the Groups worldwide production.
ISA was amended in July 2010 by the Comprehensive Iran Sanctions, Accountability and Divestment Act of 2010 (CISADA), which expanded the scope of ISA and restricted the Presidents ability to grant waivers. In addition to sanctionable investments in Irans petroleum sector, parties may now be sanctioned for any transaction exceeding $1 million or series of transactions exceeding $5 million in any 12-month period for knowingly providing to Iran refined petroleum products, and for knowingly providing to Iran goods, services, technology, information or support that could directly and significantly either (i) facilitate the maintenance or expansion of Irans domestic production of refined petroleum products, or (ii) contribute to the enhancement of Irans ability to import refined petroleum products. The sanctions to be imposed against violating firms generally prohibit transactions in foreign exchange by the sanctioned company, prohibit any transfers of credit or payments between, by, through or to any financial institution to the extent that such transfers or payments involve any interest of the sanctioned company, and require blocking of any property of the sanctioned company that is subject to the jurisdiction of the United States. Investments in the petroleum sector commenced prior to the adoption of CISADA appear to remain subject to the pre-amended version of ISA. The new sanctions added by CISADA would be available with respect to new investments in the petroleum sector or any other sanctionable activity occurring on or after July 1, 2010. Prior to CISADAs enactment, TOTAL discontinued now-prohibited sales of refined products to Iran.
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 at that time 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.
France and the European Union have adopted measures, based on United Nations Security Council resolutions, which restrict the movement of certain individuals and goods to or from Iran as well as certain financial transactions with Iran, in each case when such individuals, goods or transactions are related to nuclear proliferation and weapons activities or likely to contribute to their development. In July and October 2010, the European Union adopted new restrictive measures regarding Iran (the EU Measures). 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, 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 40,000 or equivalent to an Iranian individual or entity shall require a prior authorization of the competent authorities of the EU Member States.
TOTAL continues to closely monitor legislative and other developments in France, the European Union and the United States in order to determine whether its limited activities in Iran could subject it to the application of sanctions. However, the Group cannot assure that current or future regulations or developments regarding Iran will not have a negative impact on its business or reputation.
The United States also imposes sanctions based on the United Nations Security Council resolutions described above, as well as broad and comprehensive economic sanctions, which are administrated by the U.S. Treasury Departments Office of Foreign Assets Control (referred to as OFAC). These OFAC sanctions generally apply to U.S. persons and activities taking place in the United States or that are otherwise subject to U.S. jurisdiction. Since August 16, 2010, transactions between Iranian entities and non-U.S. financial institutions holding U.S. bank accounts in the United States have been subject to OFAC restrictions. Sanctions administered by OFAC target Cuba, Iran, Myanmar (Burma), Sudan and Syria. TOTAL does not believe that these sanctions are applicable to any of its activities in these countries.
In addition, many U.S. states have adopted legislation requiring state pension funds to divest themselves of securities in any company with active business operations in Iran or Sudan. 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. TOTAL has no business operations in Sudan and, to date, has not made any significant investments or industrial investments there. The Genocide Intervention Network (formerly known as Sudan Divestment Task Force) report states that TOTAL should be regarded as inactive in Sudan by the U.S. states that have adopted such divestment legislation. CISADA and the Sudan Accountability and Divestment Act, which was adopted by the U.S. Congress on December 31, 2007, support these state legislative initiatives. If TOTALs operations in Iran or Sudan 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 TOTALs securities.
For more information on TOTALs presence in Cuba, Iran, Sudan and Syria, see Item 4. Other Matters Business Activities in Cuba, Iran, Sudan and Syria.
TOTAL S.A., a French société anonyme (limited company) incorporated in France on March 28, 1924, together with its subsidiaries and affiliates, is the fifth largest publicly-traded integrated international oil and gas company in the world.(1)
With operations in more than 130 countries, TOTAL has activities in every sector of the oil industry, including in the Upstream (oil and gas exploration, development and production, LNG) and Downstream (refining, marketing and the trading and shipping of crude oil and petroleum products) segments.
TOTAL also has operations in Base Chemicals (petrochemicals and fertilizers) and Specialty Chemicals, mainly for the industrial market. In addition, TOTAL has interests in the coal mining and power generation sectors.
(1) Based on market capitalization (in dollars) as of December 31, 2010.
TOTAL began its Upstream operations in the Middle East in 1924. Since that time, the Company has grown and expanded its operations worldwide. Early in 1999 the Company acquired control of PetroFina S.A. and in early 2000, the Company acquired control of Elf Aquitaine S.A. (hereafter referred to as Elf Aquitaine or Elf).
The Companys registered office is 2, place Jean Millier, La Défense 6, 92400 Courbevoie, France. Its telephone number is +33 (0)1 47 44 45 46.
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.
TOTAL S.A. is registered in France with the Nanterre Trade Register under the registration number 542 051 180.
TOTALs worldwide operations are conducted through three business segments: Upstream, Downstream, and Chemicals. The table below gives information on the geographic breakdown of TOTALs activities and is taken from Note 5 to the Consolidated Financial Statements included elsewhere herein.
Rest of
North
(M)
France
Europe
America
Africa
Rest of world
Total
2010
Non-Group sales(a)
36,820
72,636
12,432
12,561
24,820
159,269
Property, plant and equipment, intangible assets, net
5,666
14,568
9,584
20,166
13,897
63,881
Capital expenditures
1,062
2,629
3,626
4,855
4,101
16,273
2009
Non-Group sales(a)
32,437
60,140
9,515
9,808
19,427
131,327
Property, plant and equipment, intangible assets, net
6,973
15,218
8,112
17,312
11,489
59,104
Capital expenditures
1,189
2,502
1,739
4,651
3,268
13,349
2008
Non-Group sales(a)
43,616
82,761
14,002
12,482
27,115
179,976
Property, plant and equipment, intangible assets, net
7,260
13,485
5,182
15,460
10,096
51,483
Capital expenditures
1,997
2,962
1,255
4,500
2,926
13,640
(a)
Non-Group sales from continuing operations.
Upstream
TOTALs Upstream segment includes the Exploration & Production and Gas & Power divisions. The Group has exploration and production activities in more than forty countries and produces oil or gas in thirty countries. The Groups Gas & Power division 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.
Exploration & Production
Exploration and development
TOTALs Upstream segment aims at continuing to combine long-term growth and profitability at the level of the best in the industry.
TOTAL evaluates exploration opportunities based on a variety of geological, technical, political and economic factors (including taxes and license terms), and on projected oil and gas prices. Discoveries and extensions of existing fields accounted for approximately 46% of the 2,445 Mboe added to the Upstream segments proved reserves during the three-year period ended December 31, 2010 (before deducting production and sales of reserves in place and adding any acquisitions of reserves in place during this period). The remaining 54% comes from revisions of previous estimates.
In 2010, the exploration investments of consolidated subsidiaries amounted to 1,472 million (comprising exploration bonuses included in the unproved property acquisition costs). The main exploration investments were made in Angola, Norway, Brazil, the United Kingdom, the United States, Indonesia, Nigeria and Brunei. In 2009, the
exploration investments of consolidated subsidiaries amounted to 1,486 million (comprising exploration bonuses included in the unproved property acquisition costs). The main exploration investments were made in the United States, Angola, the United Kingdom, Norway, Libya, Nigeria and the Republic of the Congo. In 2008, exploration investments of consolidated subsidiaries amounted to 1,243 million (comprising exploration bonuses included in the unproved property acquisition costs) notably in Angola, Nigeria, Norway, the United Kingdom, Australia, the United States, Libya, Brunei, Gabon, Cameroon, Indonesia, China, the Republic of the Congo and Canada.
The Groups consolidated Exploration & Production subsidiaries development investments amounted to 8 billion in 2010, primarily in Angola, Nigeria, Kazakhstan, Norway, Indonesia, the Republic of the Congo, the United Kingdom, the United States, Canada, Thailand, Gabon and Australia. The Groups consolidated Exploration & Production subsidiaries development investments amounted to nearly 8 billion in 2009, primarily in Angola, Nigeria, Norway, Kazakhstan, Indonesia, the Republic of the Congo, the United Kingdom, the United States, Gabon, Canada, Thailand, Russia and Qatar. In 2008, development investments amounted to 7 billion, predominantly in Angola, Nigeria, Norway, Kazakhstan, Indonesia, the Republic of the Congo, the United Kingdom, Gabon, Canada, the United States, and Qatar.
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.
TOTALs oil and gas reserves are consolidated annually, taking into account, among other factors, levels of production, field reassessment, additional reserves from discoveries and acquisitions, disposal of reserves and other economic factors. Unless otherwise indicated, any reference to TOTALs proved reserves, proved developed reserves, proved undeveloped reserves and production reflects the Groups entire share of such reserves or such production. TOTALs worldwide proved reserves include the proved reserves of its consolidated subsidiaries as well as its proportionate share of the proved reserves of equity affiliates and of two companies accounted for under the cost method. For further information concerning changes in TOTALs proved reserves for the years ended December 31, 2010, 2009 and 2008, see 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.
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).
Proved reserves
In accordance with the amended Rule 4-10 of Regulation S-X, proved reserves for the years ended on or after December 31, 2009, 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 2010 and 2009 were respectively $79.02/b and $59.91/b for Brent crude. The proved reserves for the year ended December 31, 2008 were calculated using December 31 price ($36.55/b).
As of December 31, 2010, TOTALs combined proved reserves of oil and gas were 10,695 Mboe (53% of which were proved developed reserves). Liquids (crude oil, natural gas liquids and bitumen) represented approximately 56% of these reserves and natural gas the remaining 44%. These reserves were located in Europe (mainly in Norway and the United Kingdom), in Africa (mainly in Angola, Gabon, Libya, Nigeria and the Republic of the Congo), in the Americas (mainly in Canada, the United States, Argentina, and Venezuela), in the Middle East (mainly in Qatar, the United Arab Emirates, and Yemen), and in Asia (mainly in Indonesia and Kazakhstan).
As of December 31, 2009, TOTALs combined proved reserves of oil and gas were 10,483 Mboe (56% of which were proved developed reserves). Liquids (crude oil, natural gas liquids and bitumen) represented approximately 54% of these reserves and natural gas the
remaining 46%. These reserves were located in Europe (mainly in Norway and the United Kingdom), in Africa (mainly in Angola, Gabon, Libya, Nigeria and the Republic of the Congo), in the Americas (mainly in Canada, the United States, Argentina, and Venezuela), in the Middle East (mainly in Oman, Qatar, the United Arab Emirates, and Yemen), and in Asia (mainly in Indonesia and Kazakhstan).
As of December 31, 2008, TOTALs combined proved reserves of oil and gas were 10,458 Mboe (50% of which were proved developed reserves). Liquids represented approximately 54% of these reserves and natural gas the remaining 46%. These reserves were located in Europe (mainly in Norway and the United Kingdom), in Africa (mainly in Algeria, Angola, Gabon, Libya, Nigeria and the Republic of the Congo), in the Americas (mainly in Canada, Bolivia, Argentina, and Venezuela), in the Middle East (mainly in Oman, Qatar, the United Arab Emirates, and Yemen), and in Asia (mainly in Indonesia and Kazakhstan).
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 30% of TOTALs reserves as of December 31, 2010). 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 retrievable 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 lead to a decrease in TOTALs reserves.
Production
For the full year 2010, average daily oil and gas production was 2,378 kboe/d compared to 2,281 kboe/d in 2009.
Liquids accounted for approximately 56% and natural gas accounted for approximately 44% of TOTALs combined liquids and natural gas production in 2010.
The table on the next page sets forth by geographic area TOTALs 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 frequently acts 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 TOTALs producing assets.
As in 2009 and 2008, substantially all of the liquids production from TOTALs Upstream segment in 2010 was marketed by the Trading & Shipping division of TOTALs Downstream segment. See the table Business Overview Trading & Shipping Supply and sales of crude oil.
The majority of TOTALs natural gas production is sold under long-term contracts. However, its North American production, and to some extent 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 TOTALs long-term contracts, notably in Argentina, Indonesia, Nigeria, Norway and Qatar, 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 2011-2013 to be 3,665 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. See Supplemental Oil and Gas Information (Unaudited).
PRESENTATION OF PRODUCTION ACTIVITIES BY GEOGRAPHIC AREA
The table below sets forth, by country, TOTALs producing assets, the year in which TOTALs activities started, the Groups interest in each asset and whether TOTAL is operator of the asset.
TOTALs producing assets as of December 31, 2010(a)
Deir Ez Zor (Al Mazraa, Atalla North, Jafra, Marad, Qahar, Tabiyeh) (100.00%)(h)
Yemen
1987
Kharir/Atuf (bloc 10) (28.57%)
Various fields onshore (Block 5) (15.00%)
(a)
The Groups interest in the local entity is approximately 100% in all cases except for Total Gabon (58.3%), Total E&P Cameroon (75.80%) and certain entities in the United Kingdom, Algeria, Abu Dhabi and Oman (see notes b through i below).
(b)
TOTAL has an indirect 19.41% interest in the Ourhoud field and a 48.83% indirect interest in the RKF field through its interest in CEPSA (equity affiliate).
(c)
TOTAL has a 35.8% indirect interest in Elgin Franklin through its interest in EFOG.
(d)
Through ADMA (equity affiliate), TOTAL has a 13.33% interest and participates in the operating company, Abu Dhabi Marine Operating Company.
(e)
Through ADPC (equity affiliate), TOTAL has a 9.50% interest and participates in the operating company, Abu Dhabi Company for Onshore Oil Operation.
(f)
TOTAL has a direct interest of 4.00% in Petroleum Development Oman LLC, operator of Block 6, in which TOTAL has an indirect interest of 4.00% via Pohol (equity affiliate). 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).
(g)
TOTAL has a direct interest of 2.00% in Block 53.
(h)
Operated by DEZPC which is 50.00% owned by TOTAL and 50.00% owned by SPC.
(i)
TOTAL has an indirect 34.18% interest in the Caracara Block, 8.14% in the San Jacinto/Rio Paez Block and 7.32% in the Espinal Block through its interest in CEPSA (equity affiliate).
In 2010, TOTALs production in Africa was 756 kboe/d, representing 32% of the Groups overall production, compared to 749 kboe/d in 2009 and 783 kboe/d in 2008.
In Algeria, TOTALs production amounted to 41 kboe/d in 2010, compared to 74 kboe/d in 2009 and 79 kboe/d in 2008. This decline is mainly due to the termination of the Hamra contract in October 2009. The Groups production came from its direct interest in the TFT field (Tin Fouyé Tabenkort, 35%) and from its 48.83% interest in CEPSA(1), a partner of Sonatrach (the Algerian national oil and gas company) on the Ourhoud and Rhourde El Krouf fields. TOTAL also holds a direct 37.75% interest in the Timimoun gas project alongside Sonatrach (51%) and CEPSA (11.25%) as well as a 47% interest in the Ahnet gas project alongside Sonatrach (51%) and Partex (2%).
On the TFT field, the compression project commissioned in 2010 is expected to extend plateau production to 185 kboe/d.
Basic engineering studies for the Timimoun project were launched in 2010 following approval by the ALNAFT national agency. Start-up of the project is scheduled in 2014 with commercial production of natural gas estimated at approximately 160 Mcf/d (1.6 Bm3/y) at plateau.
As part of the Ahnet project, a development plan is expected to be submitted to the authorities before mid-2011, with start-up of production scheduled for 2015 and an expected plateau production of at least 400 Mcf/d (4 Bm3/y).
In Angola, the Groups production was 163 kboe/d in 2010, compared to 191 kboe/d in 2009 and 205 kboe/d in 2008. Production comes mainly from Blocks 17, 0 and 14. Highlights of the period 2008 to 2010 included several discoveries on Blocks 15/06 and 17/06, and progress on the major Pazflor and CLOV projects.
Deep-offshore Block 17 (40%, operator) is TOTALs principal asset in Angola. It is composed of four major zones: Girassol, Dalia, Pazflor and CLOV.
On the Girassol pole, production from the Girassol, Jasmim and Rosa fields was more than 190 kb/d in 2010.
On the Dalia pole, production was more than 240 kb/d in 2010.
On the third pole, Pazflor, comprised of the Perpetua, Zinia, Hortensia and Acacia fields, production is scheduled to begin in late 2011. This project provides for the installation of an FPSO with a production capacity of 220 kb/d.
The development of CLOV, the fourth pole, was launched in 2010 with the award of the main contracts. This development will result in the installation of a fourth FPSO with a production capacity of 160 kb/d. Start-up of production is expected in 2014.
On Block 14 (20%), production on the Tombua-Landana field started in August 2009 and adds to production from the Benguela-Belize-Lobito-Tomboco and Kuito fields.
On ultra-deep offshore Block 32 (30%, operator), appraisal is continuing and pre-development studies for a first production zone in the central/southeastern portion of the block are underway (Kaombo project).
On Block 15/6 (15%), four major discoveries were announced in 2010. Studies are underway to demonstrate the feasibility of a first development area that would include the discoveries located on the northwest portion of the block.
TOTAL also has operations on exploration Blocks 33 (55%, operator) and 17/06 (30%, operator).
At year-end 2010, TOTAL sold its 5% interest in Block 31.
TOTAL is also developing in LNG through the Angola LNG project (13.6%) with the construction of a gas liquefaction plant near Soyo. The plant will be supplied in particular by the gas associated with production from Blocks 0, 14, 15, 17 and 18. Construction work is ongoing and start-up is expected in 2012.
In Cameroon, the Groups production was 9 kboe/d in 2010, compared to 12 kboe/d in 2009 and 14 kboe/d in 2008.
In November 2010, TOTAL finalized an agreement in principle with Perenco to sell the Groups 75.8% interest in its Exploration & Production subsidiary in Cameroon. The agreement is subject to the approval by the Cameroonian authorities.
In Côte dIvoire, TOTAL signed in October 2010 an agreement to acquire a 60% interest (operator) in the CI-100 exploration license. The transaction has been approved by the relevant authorities. The 2,000 km2 license is located approximately 100 km southeast of Abidjan in water depths ranging from 1,500 to 3,100 meters. Exploration work will include a new 1,000 km2 3D seismic survey, which will complete coverage of the block, and a first well is expected to be drilled in 2012.
(1) In February 2011, TOTAL signed an agreement to dispose of its 48.83% interest in CEPSA. The transaction is conditioned on obtaining all requisite approvals.
In Egypt, TOTAL signed a concession agreement in February 2010 and became operator of Block 4 (El Burullus offshore Est) with an interest of 90%. The license, located in the Nile Basin where a number of gas discoveries have been made, covers a 4-year initial exploration period and includes a commitment to carrying out 3D seismic work and drilling exploration wells. The seismic campaign started in November 2010 and ended in February 2011.
In Gabon, the Groups share of production was 67 kboe/d in 2010, compared to 71 kboe/d in 2009 and 76 kboe/d in 2008, due to the natural decline of fields. Total Gabon(1) is one of the Groups oldest subsidiaries in sub-Saharan Africa.
On the Anguille field, five development wells were drilled in 2010 from existing platforms and the construction of a new well platform has been launched.
On the deep-offshore Diaba license (Total Gabon 63.75%, operator), following the 2D seismic survey that was shot in 2008 and 2009, a 6,000 km2 3D seismic was shot in 2010.
Licenses for the Avocette and Coucal fields have been renewed in the form of an operating and production sharing agreement effective as of January 1, 2011, each for a 10-year period renewable for two subsequent 5-year periods.
Total Gabon farmed into the onshore Mutamba-Iroru (50%), DE7 (30%), and Nziembou (20%) exploration licenses in 2010.
In Libya, the Groups production was 55 kb/d in 2010, compared to 60 kb/d in 2009 and 74 kb/d in 2008. Declining production was primarily due to the implementation of OPEC quotas and new contractual provisions for Blocks C 17 (75%)(2), C 137 (75%)(2), NC 115 (30%)(2) and NC 186 (24%)(2) on which TOTAL is a partner. The EPSA IV agreements (exploration and production sharing agreements) on Blocks C 137 and C 17 were ratified by the Libyan government in January 2010 and now extend to 2032.
Having regard to the security context in Libya in the first quarter of 2011, the Groups production in Libya has been significantly reduced since early March. Furthermore, the Group is reviewing the impacts on its operations and the measures to be taken for the projects mentioned below.
On Block C 17, the Dahra and Garian fields are in the development phase.
On Block C 137, drilling of two offshore exploration wells is planned for 2011.
On Blocks NC 115 and NC 186, the nearly 5,000 km2 seismic campaign is expected to be completed in 2011.
On the Murzuk Basin, following a successful appraisal well drilled on the discovery made on a portion of Block NC 191 (100%(2), operator), a development plan was submitted to the authorities in 2009.
In December 2010, the Group relinquished Block 42 2/4 (60%(2), operator) located in the Cyrenaic Basin at the contract expiration date following an exploration wells disappointing results.
In Madagascar, TOTAL acquired in 2008 a 60% interest in the Bemolanga permit (operator), which contains oil sand accumulations. A first appraisal phase was launched to confirm the bitumen resources needed for a mining development. Drilling operations were carried out in two phases during the dry season between July and November 2009 and between April and July 2010.
In Mauritania, TOTAL has exploration operations on the Ta7 and Ta8 licenses (60%, operator), located in the Taoudenni Basin alongside Sonatrach (20%) and Qatar Petroleum International (20%).
On the Ta8 license, drilling of the exploration well ended in 2010. Results from the well are disappointing.
On Block Ta7, shooting of a 1,000 km 2D seismic started in 2011.
In Nigeria, the Groups production amounted to 301 kboe/d in 2010, compared to 235 kboe/d in 2009 and 246 kboe/d in 2008. This increase is due in particular to improved security conditions in the Niger Delta. TOTAL has been present in Nigeria since 1962. It operates seven production licenses (OML) out of the forty-four in which it holds an interest, and two exploration licenses (OPL) out of the eight in which it holds an interest. The Group is also active in LNG through Nigeria LNG and the Brass LNG project. In 2010, TOTAL acquired a 45.9% interest in Block 1 in the Joint Development Zone governed by Nigeria and São Tomé and Príncipe and was awarded operatorship in this block.
TOTAL holds a 15% interest in the Nigeria LNG gas liquefaction plant, located on Bonny Island, with an overall capacity of 22 Mt/y of LNG. In 2010, an improvement in the security situation for onshore facilities resulted in increased LNG production. NLNGs utilization rate was approximately 72% in 2010, compared to approximately 50% in 2009.
(1) Total Gabon is a Gabonese company whose shares are listed on Euronext Paris. TOTAL holds 58%, the Republic of Gabon holds 25% and the public float is 17%.
Preliminary work prior to launching the Brass LNG project (17%), which calls for the construction of two trains, each with a capacity of 5 Mt/y, continued in 2010.
TOTAL strengthened its ability to supply gas to the LNG projects in which it has interests and to meet the growing domestic demand in gas:
On the OML 136 license (40%), the positive results for the Agge 3 appraisal well confirmed the development potential of the license. Development studies are underway.
As part of its joint venture with the Nigerian National Petroleum Corporation (NNPC), TOTAL launched a project to increase the production capacity of the OML 58 license (40%, operator) from 370 Mcf/d to 550 Mcf/d of gas in 2011. A second phase of this project, which is currently being assessed, is expected to allow the development of other reserves through these facilities.
On the OML 112/117 licenses (40%), TOTAL continued development studies in 2010 for the Ima gas field.
On the OML 102 license (40%, operator), TOTAL is expected to make the final investment decision for the Ofon phase 2 project in 2011 with a start-up scheduled in 2014. The Group also launched in 2010 an appraisal campaign for the Etisong field, located 15 km from the Ofon field, which is currently producing.
On the OML 130 license (24%, operator), the Akpo field, which started up in March 2009, reached in 2010 plateau production of 225 kboe/d (in 100%). The Group is actively developing the Egina field, for which a development plan was approved by the Nigerian authorities. Basic engineering studies carried out in Nigeria are now completed and call for tenders for the projects have been launched.
On the OML 138 license (20%, operator), development of the Usan project (180 kb/d, production capacity) continued in 2010, in particular with the drilling of production wells, the construction of the FPSO and the start of the installation of sub-sea equipment. Production is expected to start-up in 2012.
TOTAL also consolidated deep offshore positions with the ongoing development of the Bonga Northwest project on the OML 118 license (12.5%).
Improved security conditions in the Niger Delta region resulted in a substantial increase in the production operated by the Shell Petroleum Development Company (SPDC) joint venture, in which TOTAL owns 10%. The Soku processing plant resumed operations in 2009 and the Gbaran-Ubie development project was completed in 2010 with the commissioning of the 1 Bcf/d production facility.
In 2010, TOTAL disposed of the interests it held (10%) through the operated SPDC joint venture in the OML 4, 38 and 41 licenses.
In the Republic of the Congo, the Groups share of production was 120 kboe/d in 2010, compared to 106 kboe/d in 2009 and 89 kboe/d in 2008.
On the Moho Bilondo field (53.5%, operator), which started up in April 2008, drilling of development wells continued in 2010. The field reached plateau production of 90 kboe/d (in 100%) in June 2010. Growth potential of the northern part of the field was confirmed by the Moho North Marine 3 appraisal well drilled at year-end 2008 following the Moho North Marine 1 and 2 discoveries, and later in 2009 by the Moho North Marine 4 exploration well that discovered new resources. Finally, two positive appraisal wells (Bilondo Marine 2 & 3) drilled at year-end 2010 in the southern portion of the field confirmed an additional growth potential as an extension of existing facilities.
Production on Libondo (65%, operator), which is part of the Kombi-Likalala-Libondo operating license, started up in March 2011. Anticipated plateau production is 8 kb/d (in 100%). A substantial portion of the equipment was sourced locally in Pointe-Noire through the redevelopment of a construction site that had been idle for several years.
In Sudan, the Group holds interests in an exploration license in the southern part of the country, although no activity is currently underway in this country. For additional information on TOTALs operations in Sudan, see Other Matters Business Activities In Cuba, Iran, Sudan and Syria.
North America
In 2010, TOTALs production in North America was 65 kboe/d, representing 3% of the Groups overall production, compared to 24 kboe/d in 2009 and 14 kboe/d in 2008.
In Canada, TOTAL signed in December 2010 a strategic partnership with Suncor related to the Fort Hills and Joslyn mining projects and the Voyageur upgrader. This partnership allows TOTAL to reorganize around two major poles the different oil sands assets that it has acquired over the last few years: a mining and upgrading pole, which includes the TOTAL-operated Joslyn (38.25%) and Suncor-
operated Fort Hills (39.2%) mining projects as well as the Suncor-operated Voyageur upgrader (49%), and a SAGD(1) pole focused on Surmonts (50%) ongoing development. The Group also holds a 50% interest in the Northern Lights (operator) mining project and 100% of a number of leases (Oil Sand Leases) acquired through several auction sales. The Groups 2010 production amounted to 10 kb/d, compared to 8 kb/d in 2009 and 2008.
On the Surmont lease, commercial production in SAGD mode from the first development phase (Surmont Phase 1A) started in late 2007.
Construction work for phases 1B and 1C was completed, which should allow these phases to reach production level estimated at 24 kb/d (in 100%). The wells of phase 1B gradually started production in 2009 and 2010 and those of phase 1C are expected to be connected and to start production in 2011.
In early 2010, the partners of the project decided to launch the construction of the second phase of development. Start-up of production from Surmont Phase 2 is scheduled in 2015 and overall production capacity from Surmont (phases 1 and 2) is expected to increase to 110 kb/d (in 100%).
The Joslyn lease, located approximately 140 km north of Surmont, is expected to be developed through mining in two phases of 100 kb/d of bitumen each.
The comprehensive review of the first phase (Joslyn North Mine), notably to meet the requirements of the February 2009 new regulation related to tailings management, was completed in February 2010 concurrent with the filing of an updated administrative file. Continuation of the preparation work for Joslyn North Mine was approved in early March 2010 and basic engineering studies were launched that are expected to end in mid-2011. Public hearings that are necessary for the project to be approved by the Canadian authorities were held in September and October 2010. The project was recommended as being in the publics interest on January 27, 2011, subject to TOTAL satisfying twenty conditions mainly related to the protection of the environment. Preliminary site preparation work is expected to be carried out from the winter 2011-2012 and production is scheduled to start in 2017/2018. However, the final schedule is subject to the Energy Resources Conservation Boards (ERCB) administrative approval process. As part of the partnership agreement signed at year-end 2010 with Suncor, the Group decreased its interest in Joslyn to 38.25% from 75%.
TOTAL closed in September 2010 the acquisition of UTS and its sole asset: a 20% interest in the Fort Hills lease. In December 2010, as part of their partnership, TOTAL acquired from Suncor an additional 19.2% interest in the Fort Hills lease and increased its interest to 39.2%. Start-up of the Fort Hills project, which was approved by the relevant authorities for a first development phase of 160 kb/d, is expected in 2016.
TOTAL also acquired in late December 2010 a 49% interest in Suncors Voyageur upgrader project. TOTAL and Suncor agreed to develop the Fort Hills and Voyageur projects in parallel. This Voyageur upgrader project that Suncor mothballed at year-end 2008 will resume in 2011 and will start up concurrently with the Fort Hills project. As a consequence, the Group has abandoned its upgrader project in Edmonton.
In 2008, the Group closed the acquisition of Synenco, the two principal assets of which are a 60% interest in the Northern Lights project and 100% of the adjacent McClelland lease. In early 2009, the Group sold to Sinopec, the other partner in the project, a 10% share in the Northern Lights project and a 50% share in the McClelland lease, reducing its interest in each of the assets to 50%. The Northern Lights project, located approximately 50 km north of Joslyn, is expected to be developed through mining techniques.
In the United States, the Groups 2010 production amounted to 55 kboe/d, compared to 16 kboe/d in 2009 and 6 kboe/d in 2008. This increase is due in particular to the acquisition of an interest in the Barnett Shale Basin at year-end 2009.
In the Gulf of Mexico:
The deep-offshore Tahiti oil field (17%) started producing in May 2009 and rapidly reached plateau production of 135 kboe/d. Phase 2 was launched in September 2010 with the drilling of the first water injection well.
Development of the first phase of the deep-offshore Chinook project (33.33%) is ongoing. The production test is scheduled to start in the first half of 2011.
The TOTAL (40%) Cobalt (60%, operator) alliances exploration drilling campaign was
launched in 2009 and the drilling of the first wells produced disappointing results. This campaign was disrupted due to the U.S. governments moratorium on offshore drilling operations from May to October 2010 and may resume by mid-2011. In April 2009, TOTAL and Cobalt had signed an agreement related to the merger of their deep offshore acreage. Cobalt is operating the exploration phase.
In April 2010, the Group disposed of its interests in the Matterhorn and Virgo operated fields.
Following the signature of an agreement in December 2009, a joint venture was set up with Chesapeake to produce shale gas in the Barnett Shale Basin, Texas. As part of this joint venture, TOTAL holds 25% of Chesapeakes portfolio in the Barnett Shale area. In 2010, 400 wells were drilled to increase gas production from 700 Mcf/d at the beginning of the year to 800 Mcf/d at year-end. Engineers from TOTAL are assigned to the teams led by Chesapeake.
In January 2009, the Group closed the acquisition of a 50% interest in American Shale Oil LLC (AMSO) to develop oil shale technology. The pilot to develop this technology is underway in Colorado.
In Alaska, TOTAL acquired in 2008 a 30% interest in several onshore exploration blocks known as White Hills. Most of them were relinquished in mid-2009 following disappointing results.
In Mexico, TOTAL is conducting various studies in cooperation with state-owned PEMEX under a technical cooperation agreement signed in 2003 which is in the process of being renewed.
South America
In 2010, TOTALs production in South America was 179 kboe/d, representing 8% of the Groups overall production, compared to 182 kboe/d in 2009 and 224 kboe/d in 2008.
In Argentina, where TOTAL has been present since 1978, the Group operates a quarter of the countrys gas production(1). The Groups production was 83 kboe/d in 2010, compared to 80 kboe/d in 2009 and 81 kboe/d in 2008.
In the Neuquén Basin, the connection of satellite discoveries and an increase in compression capacity resulted in the extension of the San Roque (24.7%, operator) and Aguada Pichana (27.3%, operator) fields plateau production.
In 2009, TOTAL and the Argentinean authorities signed an agreement extending the Aguada Pichana and San Roque concessions for ten years (from 2017 to 2027). As part of this agreement, 3D seismic was shot in late 2009 in the Las Carceles canyons area to allow the development of Aguada Pichana to continue westward.
In early 2011, TOTAL acquired interests in four licenses located in the Neuquén basin in order to assess their shale gas potential. The Group acquired 42.5% interests in and the operatorship of the Aguada de Castro and Pampa las Yeguas II licenses, a 40% interest in the Cerro Las Minas license and a 45% interest in the Cerro Partido license.
In Tierra del Fuego, where the Group notably operates the offshore Carina and Aries fields (37.5%), gas production capacity increased from 424 Mcf/d to 565 Mcf/d in 2007 thanks to the installation of a fourth medium-pressure compressor to debottleneck the facilities. Work to increase the capacity of the pipeline that routes the gas to the region of Buenos Aires was completed in July 2010. This allowed the Group to increase production up to the maximum capacity of the processing plant during the southern winter.
In Bolivia, the Groups share of production, primarily gas, amounted to 20 kboe/d in 2010, stable compared to 2009, compared to 22 kboe/d in 2008. TOTAL holds interests in six licenses: three producing licenses San Alberto and San Antonio (15%) and Block XX Tarija Oeste (41%); and three licenses in the exploration or appraisal phase Aquio and Ipati (60%, operator) and Rio Hondo (50%).
Production started up in February 2011 on the gas and condensates Itaú field located on Block XX Tarija Oeste; it is routed to the existing facilities of the neighboring San Alberto field. In 2010, TOTAL decreased its interest to 41% in Block XX Tarija Oeste after divesting 34% and is no longer the operator.
In 2004, TOTAL discovered the Incahuasi gas field on the Ipati Block. Following the interpretation of the 3D seismic shot in 2008, an appraisal well is ongoing on the adjacent Aquio Block to confirm the extension of the discovery to the north. In 2010, TOTAL signed an agreement to dispose of 20% in the Aquio and Ipati licenses. Under this agreement, which is subject to the approval by the Bolivian authorities, TOTALs interest in the licenses will be 60%.
(1) Source: Argentinean Ministry of Federal Planning, Public Investment and Services Energy Secretary.
In 2008, TOTAL entered into a cooperation agreement with Gazprom and Yacimientos Petrolíferos Fiscales Bolivianos to explore the Azero Block as part of a joint venture company. TOTAL and Gazprom will be partners with equal interests in this joint venture company.
In Brazil, TOTAL holds interests in three exploration blocks: Blocks BC-2 (41.2%) and BM-C-14 (50%) in the Campos Basin, and Block BM-S-54 (20%) in the Santos Basin.
On Block BC-2, following seismic reprocessing, a pre-salt prospect was found under the Xerelete (formerly Curió) discovery made in 2001 at a water depth of 2,400 m.
The southern extremity of Xelerete is located on Block BM-C-14, which is adjacent to Block BC-2. A unitization agreement was completed by the partners on both blocks. This agreement is subject to approval by the ANP (Agência National do Petroléo).
In June 2010, the Group acquired a 20% interest in the BM-S-54 license. Preliminary assessment of data from the exploration drilling, which was completed in November 2010, was positive and a second drilling is expected in 2011.
In Colombia, where TOTAL has been present since 1973, the Groups production was 18 kboe/d in 2010, compared to 23 kboe/d in 2009 and 2008. Following the termination of the Santiago de Los Andes license, TOTAL relinquished the Cupiagua field, and its interest in the joint venture that owns the two remaining licenses (that cover the Cusiana field) decreased to 11.6% from 19%. TOTAL also has a 50% interest in the Niscota exploration license. TOTAL is also active in the country through its interest in CEPSA(1), which has operated the Caracara Block since 2008.
On Cusiana, construction of the facilities intended to increase gas production capacity from 180 Mcf/d to 250 Mcf/d was completed in December 2010. In addition, start up of a project to extract 6 kb/d of LPG is expected in 2011.
On Niscota, drilling of the Huron-1 well led to the discovery in 2009 of a gas and condensate field. A 3D seismic survey completed in 2010 aimed at determining the size of the discovery and the location of new appraisal wells. Drilling of an appraisal well is expected in 2011.
In French Guiana, TOTAL acquired a 25% interest in the Guyane Maritime license in December 2009. The acquisition is subject to approval by the French authorities. The license, located about 150 km off the coast, covers an area of approximately 32,000 km2 in water depths ranging from 2,000 to 3,000 meters. 3D seismic acquisition and interpretation work were carried out in 2009 and 2010. Drilling of an exploration well is expected in 2011.
In Trinidad & Tobago, where TOTAL has been present since 1996, the Groups production was 3 kb/d in 2010, compared to 5 kb/d in 2009 and 6 kb/d in 2008. TOTAL holds a 30% interest in the offshore Angostura field located on Block 2C. A second phase, for the development of gas reserves, is underway, with production expected to begin in the second quarter of 2011.
In Venezuela, where TOTAL has been present since 1980, the Groups production was 55 kboe/d in 2010, compared to 54 kboe/d in 2009 and 92 kboe/d in 2008. TOTAL holds interests in PetroCedeño (30.323%), Yucal Placer (69.5%) and in the offshore exploration Block 4, located in the Plataforma Deltana (49%).
Pursuant to the decision by the Venezuelan authorities to terminate all operating contracts signed in the 1990s, the Sincor association in which TOTAL held an interest was transformed into a mixed public/private company: PetroCedeño. Under this agreement that led to the transfer of operatorship to PetroCedeño, TOTALs interest in the project decreased from 47% to 30.323% and PDVSAs interest increased to 60%. The transformation process was completed in February 2008.
PDVSA agreed to compensate TOTAL for the reduction of its interest in Sincor by assuming $326 million of debt and by paying, mostly in crude oil, $834 million. The compensation process was completed in 2009.
On Block 4, the exploration campaign, which involved three wells, was completed in 2007. In 2008, the authorities agreed to let the partners retain the Cocuina discovery zone (lots B and F) and relinquish the rest of the block.
In early 2008, TOTAL signed two agreements for joint studies with PDVSA on the Junin 10 Block, in the Orinoco Belt.
Asia-Pacific
In 2010, TOTALs production in the Asia-Pacific region was 248 kboe/d, representing 10% of the Groups overall production, compared to 251 kboe/d in 2009 and 246 kboe/d in 2008.
In Australia, where TOTAL has held leasehold rights since 2005, the Group owns 24% of the Ichthys project, 27.5% of the GLNG project and ten offshore exploration licenses,
(1) In February 2011, TOTAL signed an agreement to dispose of its 48.83% interest in CEPSA. The transaction is conditioned on obtaining all requisite approvals.
including four that it operates, off the northwest coast in the Browse, Vulcan and Bonaparte Basins. In 2010, the Group produced 1 kboe/d due to its interest in GLNG.
FEED studies for the development of the gas and condensates Ichthys field located in the Browse Basin are ongoing. The studies launched in 2009 include a floating platform designed for gas production, treatment and export, an FPSO to stabilize and export condensates, an 885 km gas pipeline and a liquefaction plant located in Darwin.
Production capacity is expected to be 8.4 Mt/y of LNG and 1.6 Mt/y of LPG as well as production capacity of 100 kb/d of condensates. The operator plans a start-up of the field at year-end 2016.
In late 2010, TOTAL acquired a 20% interest in the GLNG project, followed by an additional 7.5% interest for which the acquisition was closed in March 2011. This integrated gas production, transport and liquefaction project is based on the development of coal gas from the Fairview, Roma, Scotia and Arcadia fields. The final investment decision was made in January 2011 and start-up is expected in 2015. LNG production is expected to eventually reach 7.2 Mt/y.
Major seismic acquisition activity occurred in 2008 on the four exploration licenses operated by TOTAL, followed by the interpretation of data in 2009. A drilling campaign involving two wells started in early 2011 on the WA403 license (60%, operator).
In 2010, following unsuccessful results, TOTAL relinquished the exploration licenses located in the Carnarvon Basin.
In Brunei, where TOTAL has been present since 1986, the Group operates the offshore Maharaja Lela Jamalulalam gas and condensates field located on Block B (37.5%). The Groups production was 14 kboe/d in 2010, compared to 12 kboe/d in 2009 and 14 kboe/d in 2008. The gas is delivered to the Brunei LNG liquefaction plant.
On Block B, a new drilling campaign started in July 2009 that includes a development well, which started production in April 2010, and two exploration wells drilled in 2010 in the southern portion of the field that discovered oil and gas. Development studies for these new reserves are underway.
On deep-offshore exploration Block CA1 (54%, operator), formerly Block J, exploration operations that had been suspended since May 2003 due to a border dispute between Brunei and Malaysia resumed in September 2010. Both countries reached a border agreement in 2009 that led to adapting the production sharing agreement signed in 2003, resulting in two new partners selected by the government of Malaysia farming into the exploration block. TOTALs share decreased to 54% from 60% and TOTAL remains the operator. A drilling campaign involving several wells is expected to start in the second half of 2011.
In China, the Group is present on the South Sulige Block, located in the Ordos Basin, in the Inner Mongolia province. Appraisal work was conducted on this block between 2006 and 2008, in particular seismic acquisition, the drilling of four new wells and tests on existing wells. The development plan proposed by TOTAL in January 2010, in partnership with China National Petroleum Corporation (CNPC), was then adjusted to take advantage of the synergies achieved with the development of CNPC-operated Great Sulige. It was adopted in November 2010 by both partners and the approval process with the authorities is ongoing.
Both partners agreed that TOTALs share in cofinancing the development would be 49% and CNPCs share would be 51% (operator). The development will be operated by CNPC where a number of specialists from TOTAL will be assigned.
In Indonesia, TOTAL has been present since 1968 with production of 178 kboe/d in 2010, compared to 190 kboe/d in 2009 and 177 kboe/d in 2008.
TOTALs operations in Indonesia are primarily concentrated on the Mahakam permit (50%, operator), which covers several gas fields, including Peciko and Tunu. TOTAL also holds an interest in the Sisi-Nubi gas field (47.9%, operator). TOTAL delivers most of its natural gas production to the Bontang LNG plant operated by the Indonesian company PT Badak. The overall capacity of the eight liquefaction trains of the Bontang plant is 22 Mt/y.
In 2010, gas production operated by TOTAL amounted to 2,488 Mcf/d. The gas operated and delivered by TOTAL accounted for nearly 80% of Bontang LNGs supply. In addition to gas production, operated condensates and oil production from the Handil and Bekapai fields amounted to 49 kb/d and 23 kb/d, respectively.
On the Mahakam permit:
Drilling of additional wells on the Tunu field continued in 2010 as part of the twelfth and thirteenth development phases. The 3D seismic campaign on the central/southeastern portion of the field was completed in 2010 and drilling of development wells to discover shallow gas reservoir started in 2010.
On Peciko, following the start-up of a new platform (phase 5) in late 2008, a new phase of drilling operations (phase 7) started in 2009 and continued in 2010. New low-pressure compression capacities (phase 6) were commissioned in May 2010.
On Bekapai, debottlenecking operations to increase gas production were completed in July 2010.
Development of the South Mahakam permit continued with the award of the Engineering, Procurement and Construction contract (EPC) in August 2010 to develop the Stupa, West Stupa and East Mandu discoveries. Start-up of production is expected in early 2013.
On the Sisi-Nubi field, which began production in 2007, drilling operations continue. The gas from Sisi-Nubi is produced through Tunus processing facilities.
In 2008, a seismic campaign was conducted on the Southeast Mahakam exploration block (50%, operator), located in the Mahakam Delta. Drilling of the first exploration well (Trekulu 1) was completed in late 2010.
In May 2010, the Group acquired a 24.5% interest in two exploration blocks Arafura and Amborip VI located in the Arafura sea. Drilling of a first well started in mid-November 2010 on the Amborip VI license, which was followed by a second drilling that started in early 2011 on the Arafura license.
In October 2010, the Group closed the acquisition of a 15% interest in the Sebuku license where the Ruby gas discovery is located, the development of which was launched in mid-February 2011 with targeted production of 100 Mcf/d of natural gas and expected start-up in 2013.
In October 2010, the Group signed an agreement with the consortium Nusantara Regas (Pertamina-PGN) for the delivery of 11.75 Mt of LNG over the period 2012-2022 to a re-gasification terminal located near Jakarta.
The Heads of Agreement that TOTAL, Inpex and state-owned Pertamina signed in 2009 with a consortium of LNG buyers in Japan (Western Buyers) came into effect in March 2010. As part of this agreement, the Bontang LNG plant is expected to deliver 25 Mt of LNG to Japan for the period 2011-2020. The gas supplied will come from the Mahakam permit.
In Malaysia, TOTAL signed a production sharing contract in 2008 with state-owned Petronas for the offshore exploration Blocks PM303, which TOTAL relinquished in early 2011, and PM324 (70%, operator).
A drilling campaign in high pressure/high temperature conditions is expected to be launched in the second half of 2011 on Block PM324.
TOTAL also signed in November 2010 a new production and sharing agreement with Petronas for the deep offshore exploration Block SK 317 B (85%, operator) located off the state of Sarawak.
In Myanmar, TOTAL operates the Yadana field (31.2%). Located on offshore Blocks M5 and M6, this field produces gas that is delivered mainly to PTT (the Thai state-owned company) to be used in Thai power plants. The Yadana field also supplies the domestic market via a land pipeline and, since June 2010, via a sub-sea pipeline built and operated by Myanmars state-owned company MOGE.
The Groups production was 14 kboe/d in 2010, compared to 13 kboe/d in 2009 and 14 kboe/d in 2008.
In Thailand, the Groups production was 41 kboe/d in 2010, compared to 36 kboe/d in 2009 and 41 kboe/d in 2008. The rise in production in 2010 is the result of sustained gas demand, driven by economic growth in the country. The Groups main asset is the offshore Bongkot gas and condensates field (33.3%). PTT purchases all of the natural gas and condensates production.
On the northern portion of the Bongkot field, the 3F (three wellhead platforms) and 3G (two platforms) development phases came onstream in 2008 and 2009, respectively. New investments allow gas demand to be met and plateau production to be maintained:
the three platforms from the 3H development phase were installed in 2010 and production started up in early 2011;
phase 3J (two platforms) was launched in late 2010; and
additional low-pressure compressors have been installed to increase gas production.
The southern portion of the field (Great Bongkot South) is also being developed in several phases. This development is designed to include a processing platform, a residential platform and thirteen production platforms. Construction of the facilities, which began in 2009, accelerated in 2010 and production is expected to start up in early 2012.
In 2009, three successful exploration wells were drilled on Bongkot that are expected to be developed subsequently to maintain plateau production. In 2010, an exploration well was drilled on Bongkot North and a second well was drilled on Block G12-48 (33.3%), which neighbors the
Bongkot field. The positive results from both wells are under interpretation.
In Vietnam, TOTAL holds a 35% interest in the production sharing contract for the offshore 15-1/05 exploration block following an agreement signed in 2007 with PetroVietnam. A 1,600 km2 3D seismic survey was shot in the summer of 2008 on this block. Two oil discoveries were made on the southern portion of the block, one in November 2009 and the other in October 2010. A new drilling campaign that involves five wells started in November 2010.
In 2009, TOTAL and PetroVietnam signed a production sharing agreement for Blocks DBSCL-02 and DBSCL-03. The onshore blocks, located in the Mekong Delta region, are held by TOTAL (75%, operator) and PetroVietnam (25%). A first 2D seismic survey was shot between November 2009 and April 2010.
Commonwealth of Independent States (CIS)
In 2010, TOTALs production in the CIS was 23 kboe/d, representing 1% of the Groups overall production, compared to 24 kboe/d in 2009 and 26 kboe/d in 2008.
In Azerbaijan, TOTAL has been present since 1996 with production of 13 kboe/d in 2010, compared to 12 kboe/d in 2009 and 18 kboe/d in 2008. The Groups production is focused on the Shah Deniz field (10%). TOTAL holds a 10% interest in South Caucasus Pipeline Company, owner of the SCP (South Caucasus Pipeline) gas pipeline that transports the gas produced in Shah Deniz to the Turkish and Georgian markets. TOTAL also holds a 5% interest in BTC Co., owner of the BTC (Baku-Tbilisi-Ceyhan) oil pipeline, which connects Baku and the Mediterranean Sea.
Gas deliveries to Turkey and Georgia from the Shah Deniz field continued throughout 2010, at a lower pace for Turkey due to weaker demand. In 2010, SOCAR, the Azerbaijan state-owned company, took gas quantities superior to those provided for by the agreement.
An agreement was made with Botas, a Turkish state-owned company, to revise the price of gas sold to Turkey as part of Shah Deniz Phase 1, applicable with retroactive effect from April 15, 2008.
Development studies and business negotiations for the sale of additional gas needed to launch a second development phase in Shah Deniz continued in 2010. SOCAR and Botas signed in June 2010 a Memorandum of Understanding for the sale of additional gas volumes and the transfer conditions for volumes intended for the European market. This agreement is expected to allow FEED studies to start in 2011 for the second phase.
On the BTC oil pipeline, notably used to transport the condensates produced at Shah Deniz, equipment was installed in 2009 to inject additives to reduce drag. This resulted in the oil pipeline capacity increasing from 1 Mb/d to 1.2 Mb/d.
In 2009, TOTAL and SOCAR signed an exploration, development and production sharing agreement for a license located on the Absheron block in the Caspian Sea. TOTAL (40%) is the operator during the exploration phase and a joint operating company will manage operations during the development phase. Drilling of an exploratory well started in early 2011.
In Kazakhstan, TOTAL has held since 1992 an interest in the North Caspian license that covers notably the Kashagan field where the substantial reserves may eventually allow production to reach more than 1 Mb/d (in 100%).
The Kashagan project is expected to be developed in several phases. The development plan for the first phase (300 kb/d) was approved in February 2004 by the Kazakh authorities, allowing work to begin on the field. Drilling of development wells, which began in 2004, continued in 2010. The consortium continues to target first commercial production by year-end 2012.
In October 2008, the members of the North Caspian Sea Production Sharing Agreement (NCSPSA) consortium and the Kazakh authorities signed agreements to end the disagreement that began in August 2007. Their implementation led to a reduction of TOTALs share in NCSPSA from 18.52% to 16.81%. The operating structure was reconfigured and the North Caspian Operating Company (NCOC), a joint operating company, was entrusted with the operatorship in January 2009. NCOC supervises and coordinates NCSPSAs operations.
In Russia, where TOTAL has been present since 1989, the Groups production was 10 kboe/d in 2010, compared to 12 kboe/d in 2009 and 8 kboe/d in 2008. Production comes mainly from the Kharyaga field (40%, operator).
In 2007, TOTAL and Gazprom signed an agreement for the first phase of development on the giant Shtokman gas and condensates field, located in the Barents Sea. Under this agreement, Shtokman Development AG (TOTAL, 25%) was created in 2008 to design, build, finance and operate this first development phase whose overall production capacity is expected to be 23.7 Bm3/y (0.4 Mboe/d). Engineering studies are underway for the portion of the project that will allow the transport of gas by pipeline through the Gazprom network (offshore development, gas pipeline and onshore gas and condensates processing facilities Teriberka site),
with a final investment decision expected in 2011, and for the LNG part of the project that will allow the export of 7.5 Mt/y of LNG from a new harbor located in Teriberka, representing approximately half of the gas produced by the first development phase.
In December 2009, TOTAL closed the acquisition from Novatek of a 49% interest in Terneftegas, which holds a development and production license on the onshore Termokarstovoye field. An appraisal well was drilled in 2010, the results of which are expected to lead to a final investment decision by year-end 2011.
On the Kharyaga field, work related to the development plan of phase 3 is ongoing. This development plan is intended to maintain plateau production at the 30 kboe/d (in 100%) level reached in late 2009. In December 2009, TOTAL signed an agreement, effective January 1, 2010, to sell 10% of the field to state-owned Zarubezhneft, and decreased its interest to 40%.
In October 2009, TOTAL signed an agreement setting forth the principles of a partnership with KazMunaiGas (KMG) for the development of the Khvalynskoye gas and condensates field, located offshore in the Caspian Sea on the border between Kazakhstan and Russia, under Russian jurisdiction. Gas production is expected to be transported to Russia. Pursuant to this agreement, TOTAL is planning to acquire a 17% interest in KMGs share.
On March 2, 2011, TOTAL and Novatek signed two agreements in principle providing for:
TOTAL becoming the main international partner on the Yamal LNG project with a 20% interest, and Novatek holding a 51% interest in the project. As part of the agreement, the transaction is expected to be closed by July 2011.
TOTAL taking a 12.08% interest in Novatek with both parties intending that TOTAL increases its interest to 15% within 12 months and to 19.40% within 36 months.
Europe
In 2010, TOTALs production in Europe was 580 kboe/d, representing 24% of the Groups overall production, compared to 613 kboe/d in 2009 and 616 kboe/d in 2008.
In Denmark, TOTAL was awarded in June 2010 an 80% interest in and the operatorship for licenses 1/10 (Nordjylland) and 2/10 (Frederoskilde), following the approval by the Danish Energy Agency. These onshore licenses cover areas of 3,000 km2 and 2,300 km2, respectively, and are expected to be appraised for shale gas.
In France, the Groups production was 21 kboe/d in 2010, compared to 24 kboe/d in 2009 and 25 kboe/d in 2008. TOTALs major assets are the Lacq (100%) and Meillon (100%) gas fields, located in the southwest part of the country.
On the Lacq field, operated since 1957, a carbon capture and storage pilot was commissioned in January 2010. In connection with this project, a boiler has been modified to operate in an oxy-fuel combustion environment and the carbon dioxide emitted is captured and re-injected in the depleted Rousse field. As part of the Groups sustainable development policy, this project will allow the Group to assess one of the technological possibilities for reducing carbon dioxide emissions.
In 2010, TOTAL was awarded the Montélimar (100%) license to assess the shale gas potential of the area once authorizations to operate are given.
In Italy, the Tempa Rossa field (50%, operator), discovered in 1989 and located on the unitized Gorgoglione concession (Basilicate region), is one of TOTALs principal assets in the country.
Site preparation work started in early August 2008, but the proceedings initiated by the Prosecutor of the Potenza Court against Total Italia led to a freeze in the preparation work. New calls for tenders have been launched related to certain contracts that had been cancelled. Drilling of the Gorgoglione 2 appraisal well that started in May 2010 is ongoing. The partners on Tempa Rossa are expected to make the final investment decision in 2011 for this project that has an expected capacity of 55 kboe/d. The extension plan for the Tarente refinery export system, needed for the development of the Tempa Rossa field, was submitted to the Italian authorities in May 2010 for an approval expected in 2011. Start-up of production is currently expected in 2015.
In Norway, where the Group has been present since the mid-1960s, TOTAL holds interests in seventy-eight production licenses on the Norwegian continental shelf, fifteen of which it operates. Norway is the largest single-country contributor to the Groups production, with volumes of 310 kboe/d in 2010, compared to 327 kboe/d in 2009 and 334 kboe/d in 2008.
In the Norwegian North Sea, production was 226 kboe/d in 2010. The most substantial contribution to production, for the most part non-operated, comes from the Greater Ekofisk Area (Ekofisk, Eldfisk, Embla, etc.), located in the south.
The Greater Hild Area (Hild East, Central, West, etc.) is located in the north.
Several projects are ongoing or are under study in the Greater Ekofisk Area, where the Group has a 39.9% participation in the Ekofisk and Eldfisk fields. The Ekofisk South and Eldfisk 2 projects are expected to be launched in 2011 after receiving the approval from the Norwegian authorities.
In 2010, the Group sold its interests in the Valhall/Hod fields.
On the Greater Hild Area, the Group holds a 49% interest (operator). The development scheme was selected at year-end 2010. The project is expected to be approved in 2011 and production is scheduled to start up in 2016.
On Frigg, decommissioning is completed.
In the Norwegian Sea, the Haltenbanken area includes the Tyrihans (23.2%), Mikkel (7.7%) and Kristin (6%) fields as well as the Åsgard (7.7%) field and its satellites Yttergryta (24.5%) and Morvin (6%). Morvin started up in August 2010 as planned, with two producing wells. In 2010, the Groups production in the Haltenbanken area was 61 kboe/d.
In the Barents Sea, LNG production on Snøhvit (18.4%) started in 2007. This project includes development of the natural gas fields, Snøhvit, Albatross and Askeladd, as well as the construction of the associated liquefaction facilities. Due to design problems, the plant experienced reduced capacity during the start-up phase. A number of maintenance turnarounds were scheduled to fix the issue and the plant is now operating at its design capacity (4.2 Mt/y).
Between 2008 and 2010, exploration and appraisal work was carried out on various licenses. In the Norwegian North Sea, the oil discovery on Dagny (PL 048, 21.8%) and the Pan/Pandora (PL 120, 11%) discovery, made in 2008, substantially increased the potential of the Sleipner and Visund areas, respectively. Pan/Pandora is to be developed as a fast track satellite. The development project is expected to be launched in 2011 after receipt of approval from the Norwegian authorities. The Dagny project is scheduled for approval in 2012.
A number of discoveries were made in 2009, in particular on Beta Vest (PL 046, 10%) near Sleipner, Katla (PL 104, 10%), located south of Oseberg, and Vigdis North East (PL 089, 5.6%), located south of Snorre. Katla and Vigdis North East are expected to be developed as fast track satellites, with the approval of the projects by the partners on both licenses planned for the first half of 2011. In the Central North Sea, TOTAL (40% operator) made a gas and condensate discovery in 2010 on the David structure (PL 102C -Heimdal area). The structure could be developed through a tie-back to Heimdal via Skirne-Byggve. In the Barents Sea, TOTAL was awarded in 2009 a new exploration license PL 535 (40%) during the twentieth licensing round. On this license, a 3D seismic acquisition was completed in 2009 and drilling is expected to begin in 2011. In 2011, TOTAL was awarded four new exploration licenses, including one for which TOTAL is operator, during the 2010 APA (Awards in Predefined Areas).
In the Netherlands, TOTAL has been active in natural gas exploration and production since 1964 and currently holds twenty-four offshore production permits, including twenty that it operates, and an offshore exploration permit, E17c (16.92%) awarded in 2008. In 2010, the Groups share of production amounted to 42 kboe/d, compared to 45 kboe/d in 2009 and 44 kboe/d in 2008. In 2008, TOTAL acquired Goal Petroleum (Netherlands) B.V.
On the K5F field (40.39%, operator), production began in 2008. This project is comprised of two sub-sea wells connected to the existing production and transport facilities. K5F is the first project in the world to use only electrically driven sub-sea well heads and systems.
Development of the K5CU project (49%, operator) was launched in 2009 and production started up in early 2011. This development includes four wells supported by a platform that has been installed in September 2010 and is connected to the K5A platform by a 15 km gas pipeline.
In late 2010, TOTAL disposed of 18.19% of its shares in the NOGAT gas pipeline and decreased its interest to 5%.
In the United Kingdom, TOTAL has been present since 1962 with production in 2010 of 207 kboe/d, compared to 217 kboe/d in 2009 and 213 kboe/d in 2008. 86% of this production comes from operated fields located in two major zones: the Alwyn zone in the northern North Sea, and the Elgin/Franklin zone in the Central Graben.
On the Alwyn zone, start-up of satellite fields or new reservoir compartments allowed production to be maintained. The processing and compressing capacities of the Alwyn platform increased from 530 Mcf/d to 575 Mcf/d during the summer of 2008 planned shutdown for maintenance.
The N52 well drilled on Alwyn (100%) in a new compartment of the Statfjord reservoir came onstream in February 2010 with initial flow of 15 kboe/d (gas and condensates).
The Jura field (100%), discovered in late 2006, started production in May 2008 through two sub-sea wells connected to the oil pipeline linking Forvie North and Alwyn. The production capacity of this field is 50 kboe/d (gas and condensates).
Development studies were completed on Islay (100%), a second gas and condensates discovery made in 2008 and located in a faulted panel immediately east of Jura, and the development was approved in July 2010. Start-up of production is expected in the second half of 2011 with a production capacity of 15 kboe/d.
In late 2008, TOTAL increased its interest in the Otter field from 54.3% to 81%. An agreement to dispose of this interest was reached in 2010 and is expected to be completed under two phases between 2011 and 2012.
The development of the Elgin (35.8%) and Franklin fields (35.8%), in production since 2001, contributed substantially to the Groups operations in the United Kingdom. On the Elgin field, the infill well drilled between November 2008 and September 2009 came onstream in October 2009 with production of 18 kboe/d. Drilling of a second infill well was completed in 2010 with production of 12 kboe/d starting up in May. Drilling of such a well in a high pressure/high temperature highly depleted field is a significant technical milestone.
Additional development of West Franklin through a second phase (drilling of three additional wells and installation of a new platform connected to Elgin) was approved in November 2010. This phase is expected to result in the development of approximately 85 Mboe in 100%. Start-up of production is expected at year-end 2013.
As part of an agreement signed in 2005, TOTAL acquired a 25% interest in two blocks located near Elgin and Franklin by drilling an appraisal well on the Kessog structure. This interest was increased to 50% in 2009.
In the West of Shetland area, TOTAL increased its interest to 80% in the Laggan and Tormore fields in early 2010.
The final investment decision for the Laggan/Tormore project was made in March 2010 and commercial production is scheduled to start in 2014 with an expected capacity of 90 kboe/d. The joint development scheme selected by TOTAL and its partner includes sub-sea production facilities and off-gas treatment (gas and condensates) at a plant located near the Sullom Voe terminal in the Shetland Islands. The gas would then be exported to the Saint-Fergus terminal via a new pipeline connected to the Frigg pipeline (FUKA).
In 2010, the Groups interest in the P967 license (operator), which includes the Tobermory gas discovery, increased to 50% from 43.75%. This license is located north of Laggan/Tormore.
In early 2011, a gas and condensate discovery was made on the Edradour license (75%, operator).
TOTAL holds interests in ten assets operated by third parties, the most important in terms of reserves being the Bruce (43.25%) and Alba (12.65%) fields. The Group disposed of its interest in the Nelson field (11.5%) in 2010.
Middle East
In 2010, TOTALs production in the Middle East was 527 kboe/d, representing 22% of the Groups overall production, compared to 438 kboe/d in 2009 and 432 kboe/d in 2008.
In the United Arab Emirates, where TOTAL has been present since 1939, the Groups production in 2010 was 222 kboe/d, compared to 214 kboe/d in 2009 and 243 kboe/d in 2008. The changes that have been recorded since 2008 are mainly due to the implementation of OPEC quotas.
In Abu Dhabi, TOTAL holds a 75% interest in the Abu Al Bu Khoosh field (operator), a 9.5% interest in the Abu Dhabi Company for Onshore Oil Operations (ADCO), which operates the five major onshore fields in Abu Dhabi, and a 13.3% interest in Abu Dhabi Marine (ADMA), which operates two offshore fields. TOTAL also has a 15% stake in Abu Dhabi Gas Industries (GASCO), which produces LPG and condensates from the associated gas produced by ADCO, and a 5% stake in Abu Dhabi Gas Liquefaction Company (ADGAS), which produces LNG, LPG and condensates.
In early 2009, TOTAL signed agreements for a 20-year extension of its participation in the GASCO joint venture starting on October 1, 2008.
In early 2011, TOTAL and IPIC, a government-owned entity in Abu Dhabi, signed a Memorandum of Understanding with a view to developing projects of common interest in the upstream oil and gas sectors.
The Group holds a 25% interest in Dolphin Energy Ltd. alongside Mubadala, a company owned by the government of the Abu Dhabi Emirate, to market gas produced in Qatar in particular to the United Arab Emirates.
The Group also holds a 33.3% interest in Ruwais Fertilizer Industries (FERTIL), which produces urea. FERTIL 2, a new project, was launched in 2009 to build a new granulated urea unit with a capacity of 3,500 t/d (1.2 Mt/y). This project
is expected to allow FERTIL to more than double production so as to reach nearly 2 Mt/y in January 2013.
In Iraq, TOTAL bid in 2009 and 2010 on the three calls for tenders launched by the Iraqi Ministry of Oil. The PetroChina-led consortium that includes TOTAL (18.75%) was awarded the development and production contract for the Halfaya field during the second call for tenders held in December 2009. This field is located in the province of Missan, north of Basra. The agreement became effective in March 2010 and the preliminary development plan was approved by the Iraqi authorities in late September 2010. Development operations have started. It plans for first production of nearly 70 kb/d of oil in 2012.
In Iran, the Groups production, under buyback agreements, amounted to 2 kboe/d in 2010, compared to 8 kboe/d in 2009 and 9 kboe/d in 2008. For additional information on TOTALs operations in Iran, see Other Matters Business Activities In Cuba, Iran, Sudan and Syria.
In Oman, the Groups production in 2010 was 34 kboe/d, stable compared to 2009 and 2008. The Group produces oil on Block 6 mainly and on Block 53 as well as liquefied natural gas through its interests in the Oman LNG (5.54%)/Qalhat LNG (2.04%)(1) liquefaction plant, which has a capacity of 10.5 Mt/y.
In Qatar, TOTAL has been present since 1936 and holds interests in the Al Khalij field (100%), the NFB Block (20%) in the North field, the Qatargas 1 liquefaction plant (10%), Dolphin (24.5%) and train 5 of Qatargas 2 (16.7%). The Groups production was 164 kboe/d in 2010, compared to 141 kboe/d in 2009 and 121 kboe/d in 2008. Production substantially increased with the start-up of Qatargas 2.
Production from Dolphin started during the summer of 2007 and reached its full capacity in the first quarter of 2008. The contract, signed in 2001 with state-owned 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.
Production from train 5 of Qatargas 2, which started in September 2009, reached its full capacity (7.8 Mt/y) at year-end 2009. TOTAL has owned an interest in this train since 2006. In addition, TOTAL began to off-take part of the LNG produced in compliance with the contracts signed in 2006, which provide for the purchase of 5.2 Mt/y of LNG from Qatargas 2 by the Group.
The Group also holds a 10% interest in Laffan Refinery, a 146 kb/d condensate splitter that started up in September 2009.
In Syria, TOTAL is present on the Deir Ez Zor license (100%, operated by DEZPC, 50% of which is owned by TOTAL) and through the Tabiyeh contract that became effective in October 2009. The Groups production for both assets was 39 kboe/d in 2010, compared to 20 kboe/d in 2009 and 15 kboe/d in 2008.
Three agreements were ratified:
in 2008, the 10-year extension, to 2021, of the production sharing agreement of the Deir Ez Zor license;
in 2009, the Tabiyeh agreement, which primarily provides for an increase in the production from the gas and condensates Tabiyeh field; and
in 2009, the Cooperation Framework Agreement, which provides for the development of oil projects in partnership with the Syrian company General Petroleum Corporation.
For additional information on TOTALs operations in Syria, Other Matters Business Activities In Cuba, Iran, Sudan and Syria.
In Yemen, TOTAL has been present since 1987 with production of 66 kboe/d in 2010, compared to 21 kboe/d in 2009 and 10 kboe/d in 2008.
TOTAL has an interest in the Yemen LNG project (39.62%). As part of this project, the liquefaction plant built in Balhaf on the southern coast of Yemen is supplied with the gas produced on Block 18, located near Marib in the center of the country, through a 320 km gas pipeline. The two liquefaction trains were commissioned in October 2009 and April 2010. Overall production capacity from both trains is 6.7 Mt/y of LNG.
TOTAL also has interests in the countrys two oil basins, as the operator on Block 10 (Masila Basin, East Shabwa license, 28.57%) and as a partner on Block 5 (Marib Basin, Jannah license, 15%).
In 2010, TOTAL consolidated positions in onshore exploration through the acquisition of a 36% interest in Block 72 and by increasing its interest to 50.1% from 30.9% in Block 70. TOTAL also acquired 40% interests in Blocks 69 and 71 in 2007. Appraisal of gas discoveries on Block 71 is underway. The first well drilled on Block 70 discovered positive oil shows. The potential of this discovery has yet to be assessed.
(1) Indirect interest through the 36.8% share in Qalhat LNG owned by Oman LNG.