Supplementary information on oil <strong>and</strong> natural gas (unaudited)Movements in estimated net proved reserves continuedmillion barrels of oil equivalentEurope US eTotal hydrocrabons a <strong>20</strong>09EuropeNorthSouth Africa Asia Australasia TotalAmericaAmericaUKAmericaRussia AsiaRest ofRest ofNorthRest ofSubsidiariesAt 1 January <strong>20</strong>09Developed 724 91 3,279 126 617 645 – 385 382 6,249Undeveloped 219 264 2,217 81 1,337 734 – 714 747 6,313943 355 5,496 <strong>20</strong>7 1,954 1,379 – 1,099 1,129 12,562Changes attributable toRevisions of previous estimates (13) (2) 260 9 74 (74) – (168) 7 93Improved recovery 48 7 177 1 63 40 – 45 15 396Purchases of reserves-in-place 28 – – – – – – 6 – 34Discoveries <strong>and</strong> extensions 210 – 158 17 18 124 – – 98 625Production b f (102) (16) (393) (<strong>20</strong>) (182) (152) – (86) (44) (995)Sales of reserves-in-place (28) – (1) – – – – (65) – (94)143 (11) <strong>20</strong>1 7 (27) (62) – (268) 76 59At 31 December <strong>20</strong>09 cDeveloped 680 91 3,514 135 596 613 – 455 612 6,696Undeveloped 406 253 2,183 79 1,331 704 – 376 593 5,9251,086 344 5,697 214 1,927 1,317 – 831 1,<strong>20</strong>5 12,621Equity-accounted entities (<strong>BP</strong> share) gAt 1 January <strong>20</strong>09Developed – – – – 658 – 2,495 529 – 3,682Undeveloped – – – – 586 42 1,057 218 – 1,903– – – – 1,244 42 3,552 747 – 5,585Changes attributable toRevisions of previous estimates – – – – (2) (5) 625 (32) – 586Improved recovery – – – – 104 – 8 1 – 113Purchases of reserves-in-place – – – – – – – – – –Discoveries <strong>and</strong> extensions – – – – 4 – 92 – – 96Production b f – – – – (66) – (345) (75) – (486)Sales of reserves-in-place – – – – (81) – – (142) – (223)– – – – (41) (5) 380 (248) – 86At 31 December <strong>20</strong>09 dDeveloped – – – – 623 – 2,645 377 – 3,645Undeveloped – – – – 580 37 1,287 122 – 2,026– – – – 1,<strong>20</strong>3 37 3,932 499 – 5,671Total subsidiaries <strong>and</strong> equity-accounted entities (<strong>BP</strong> share)At 1 January <strong>20</strong>09Developed 724 91 3,279 126 1,275 645 2,495 914 382 9,931Undeveloped 219 264 2,217 81 1,923 776 1,057 932 747 8,216943 355 5,496 <strong>20</strong>7 3,198 1,421 3,552 1,846 1,129 18,147At 31 December <strong>20</strong>09Developed 680 91 3,514 135 1,219 613 2,645 832 612 10,341Undeveloped 406 253 2,183 79 1,911 741 1,287 498 593 7,9511,086 344 5,697 214 3,130 1,354 3,932 1,330 1,<strong>20</strong>5 18,292aProved reserves exclude royalties due to others, whether payable in cash or in kind, where the royalty owner has a direct interest in the underlying production <strong>and</strong> the option <strong>and</strong> ability to make lifting <strong>and</strong>sales arrangements independently.bExcludes NGLs from processing plants in which an interest is held of 26 thous<strong>and</strong> barrels of oil equivalent per day.cIncludes 819 million barrels of NGLs. Also includes 552 million barrels of oil equivalent in respect of the 30% minority interest in <strong>BP</strong> Trinidad <strong>and</strong> Tobago LLC.dIncludes <strong>20</strong> million barrels of NGLs. Also includes 266 million barrels of oil equivalent in respect of the minority interest in TNK-<strong>BP</strong>.eProved reserves in the Prudhoe Bay field in Alaska include an estimated 68 million barrels of oil equivalent upon which a net profits royalty will be payable.fIncludes 34 million barrels of oil equivalent of natural gas consumed in operations, 29 million barrels of oil equivalent in subsidiaries, 5 million barrels of oil equivalent in equity-accounted entities <strong>and</strong>excludes 3 million barrels of oil equivalent of produced non-hydrocarbon components which meet regulatory requirements for sales.gVolumes of equity-accounted entities include volumes of equity-accounted investments of those entities.276 <strong>BP</strong> <strong>Annual</strong> <strong>Report</strong> <strong>and</strong> <strong>Form</strong> <strong>20</strong>-F <strong>20</strong>11
Supplementary information on oil <strong>and</strong> natural gas (unaudited)St<strong>and</strong>ardized measure of discounted future net cash flows <strong>and</strong>changes therein relating to proved oil <strong>and</strong> gas reservesThe following tables set out the st<strong>and</strong>ardized measure of discounted future net cash flows, <strong>and</strong> changes therein, relating to crude oil <strong>and</strong> natural gasproduction from the group’s estimated proved reserves. This information is prepared in compliance with FASB Oil <strong>and</strong> Gas Disclosures requirements.Future net cash flows have been prepared on the basis of certain assumptions which may or may not be realized. These include the timingof future production, the estimation of crude oil <strong>and</strong> natural gas reserves <strong>and</strong> the application of average crude oil <strong>and</strong> natural gas prices <strong>and</strong> exchangerates from the previous 12 months. Furthermore, both proved reserves estimates <strong>and</strong> production forecasts are subject to revision as further technicalinformation becomes available <strong>and</strong> economic conditions change. <strong>BP</strong> cautions against relying on the information presented because of the highly arbitrarynature of the assumptions on which it is based <strong>and</strong> its lack of comparability with the historical cost information presented in the financial statements.EuropeUKRest ofEuropeNorthAmericaRest ofNorthUS AmericaSouthAmerica$ million<strong>20</strong>11Africa Asia Australasia TotalAt 31 December <strong>20</strong>11SubsidiariesFuture cash inflows a 97,900 36,400 332,900 100 39,100 82,100 – 59,<strong>20</strong>0 53,900 701,600Future production cost b 30,500 10,900 140,700 100 10,500 16,800 – 16,000 15,600 241,100Future development cost b 8,500 2,700 32,300 – 7,600 13,<strong>20</strong>0 – 9,600 3,<strong>20</strong>0 77,100Future taxation c 37,100 15,<strong>20</strong>0 57,000 – 11,400 19,800 – 8,100 9,000 157,600Future net cash flows 21,800 7,600 102,900 – 9,600 32,300 – 25,500 26,100 225,80010% annual discount d 11,<strong>20</strong>0 3,100 55,500 – 4,100 12,500 – 9,800 13,500 109,700St<strong>and</strong>ardized measure of discountedfuture net cash flows e 10,600 4,500 47,400 – 5,500 19,800 – 15,700 12,600 116,100Equity-accounted entities (<strong>BP</strong> share) fFuture cash inflows a – – – 9,100 46,700 – 188,900 34,<strong>20</strong>0 – 278,900Future production cost b – – – 3,100 21,500 – 123,800 30,100 – 178,500Future development cost b – – – 1,900 5,000 – 15,600 2,400 – 24,900Future taxation c – – – 900 5,900 – 9,600 <strong>20</strong>0 – 16,600Future net cash flows – – – 3,<strong>20</strong>0 14,300 – 39,900 1,500 – 58,90010% annual discount d – – – 2,800 8,700 – 19,000 600 – 31,100St<strong>and</strong>ardized measure of discountedfuture net cash flows g h – – – 400 5,600 – <strong>20</strong>,900 900 – 27,800Total subsidiaries <strong>and</strong> equity-accounted entitiesSt<strong>and</strong>ardized measure of discountedfuture net cash flows 10,600 4,500 47,400 400 11,100 19,800 <strong>20</strong>,900 16,600 12,600 143,900RussiaRest ofAsiaThe following are the principal sources of change in the st<strong>and</strong>ardized measure of discounted future net cash flows:SubsidiariesEquity-accountedentities (<strong>BP</strong> share)$ millionTotal subsidiaries <strong>and</strong>equity-accountedentitiesSales <strong>and</strong> transfers of oil <strong>and</strong> gas produced, net of production costs (30,900) (5,700) (36,600)Development costs for the current year as estimated in previous year 12,800 2,900 15,700Extensions, discoveries <strong>and</strong> improved recovery, less related costs 6,600 2,800 9,400Net changes in prices <strong>and</strong> production cost 75,000 15,800 90,800Revisions of previous reserves estimates (22,000) 2,100 (19,900)Net change in taxation (18,<strong>20</strong>0) (1,400) (19,600)Future development costs (10,800) (2,700) (13,500)Net change in purchase <strong>and</strong> sales of reserves-in-place (6,500) (2,700) (9,<strong>20</strong>0)Addition of 10% annual discount 10,000 1,500 11,500Total change in the st<strong>and</strong>ardized measure during the year i 16,000 12,600 28,600aThe marker prices used were Brent $110.96/bbl, Henry Hub $4.12/mmBtu.bProduction costs, which include production taxes, <strong>and</strong> development costs relating to future production of proved reserves are based on the continuation of existing economic conditions. Futuredecommissioning costs are included.cTaxation is computed using appropriate year-end statutory corporate income tax rates.dFuture net cash flows from oil <strong>and</strong> natural gas production are discounted at 10% regardless of the group assessment of the risk associated with its producing activities.eMinority interest in <strong>BP</strong> Trinidad <strong>and</strong> Tobago LLC amounted to $1,600 million.fThe st<strong>and</strong>ardized measure of discounted future net cash flows of equity-accounted entities includes st<strong>and</strong>ardized measure of discounted future net cash flows of equity-accounted investments of thoseentities.gMinority interest in TNK-<strong>BP</strong> amounted to $1,600 million in Russia.hNo equity-accounted future cash flows in Africa because proved reserves are received as a result of contractual arrangements, with no associated costs.iTotal change in the st<strong>and</strong>ardized measure during the year includes the effect of exchange rate movements.Financial statements<strong>BP</strong> <strong>Annual</strong> <strong>Report</strong> <strong>and</strong> <strong>Form</strong> <strong>20</strong>-F <strong>20</strong>11 277
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Cover imagePhotograph of DeepseaSta
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Cross reference to Form 20-FPageIte
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Miscellaneous termsIn this document
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6 BP Annual Report and Form 20-F 20
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Chairman’s letterCarl-Henric Svan
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During the year, the remuneration c
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Business review: Group overviewBP A
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In detailFind out more online.bp.co
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BP Annual Report and Form 20-F 2011
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Below BP has asignificant presencei
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What you can measure6 Active portfo
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Business review: Group overview2012
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