SECURITIES AND EXCHANGE COMMISSION
 

      Washington, D.C. 20549
 

 

      Form 6-K
 

       Report of Foreign Issuer
 

       Pursuant to Rule 13a-16 or 15d-16 of
           the Securities Exchange Act of 1934
 


          for the period ended 03 February, 2009
 
 

           BP p.l.c.
                 (Translation of registrant's name into English)
 
 

                 1 ST JAMES'S SQUARE, LONDON, SW1Y 4PD, ENGLAND
                    (Address of principal executive offices)
 
 

     Indicate  by check mark  whether the  registrant  files or will file annual
     reports under cover Form 20-F or Form 40-F.
 
 
Form 20-F        |X|          Form 40-F
                         ---------------               ----------------
 
 

     Indicate by check mark whether the registrant by furnishing the information
     contained in this Form is also thereby  furnishing  the  information to the
     Commission  pursuant to Rule 12g3-2(b) under the Securities Exchange Act of
     1934.
 
 

Yes                            No        |X|
                         ---------------               ----------------
 
 


 

BP p.l.c.

Group results
Fourth quarter 2008

 


London 3 February 2009

FOR IMMEDIATE RELEASE

Fourth 

Third 

Fourth 

       

quarter 

quarter 

quarter 

 

Year

2007 

2008 

2008 

$ million

2008 

2007 

4,399 

8,049 

(3,344)

Profit (loss) for the period(a)

21,157 

20,845 

 
     

Inventory holding (gains) losses,

     

(1,004)

1,980 

5,931 

net of tax(b)

4,436 

(2,475)

 
             

3,395 

10,029 

2,587 

Replacement cost profit(b)

25,593 

18,370 

39 

             

8.75 

27.76 

11.32 

– per ordinary share (pence)(c)

74.02 

47.92 

 

17.90 

53.43 

13.93 

– per ordinary share (cents)

136.20 

95.85 

42 

1.07 

3.21 

0.84 

– per ADS (dollars)

8.17 

5.75 

 


·     

BP’s fourth-quarter replacement cost profit was $2,587 million, compared with $3,395 million a year ago, a decrease of 24% due largely to the significantly lower oil prices. For the full year, replacement cost profit was $25,593 million compared with $18,370 million a year ago, up 39%.




·     

Non-operating items and fair value accounting effects for the fourth quarter had a net $18 million unfavourable impact compared to a net $1,132 million unfavourable impact for the fourth quarter of 2007. For the full years of 2008 and 2007, the respective amounts were $650 million unfavourable and $571 million unfavourable - see further details on page 3. The most significant non-operating items for the fourth quarter were, on a pre-tax basis, fair value gains on embedded derivatives, which amounted to $1,562 million, and a net charge of $1,460 million for impairments and gains and losses on the sale of businesses and fixed assets.




·     

Net cash provided by operating activities for the quarter and year was $5.6 billion and $38.1 billion compared with $4.3 billion and $24.7 billion respectively a year ago.




·     

The effective tax rate on replacement cost profit for the fourth quarter was 44% and for the year was 36%; a year ago, the rates were 38% and 33% respectively. The rate in the fourth quarter reflects the impact of a loss from jointly controlled entities and the impairment of an investment, neither of which generate a corresponding credit to the group tax charge. We expect the tax rate to be in the range of 36% to 39% during 2009.




·     

Net debt at the end of the quarter was $25.0 billion compared to $26.8 billion a year ago. The ratio of net debt to net debt plus equity was 21%, compared with 22% a year ago.




·     

Total capital expenditure and acquisitions was $7.0 billion for the quarter and $30.7 billion for the year. Capital expenditure, excluding acquisitions and asset exchanges and excluding the accounting for our transactions with Husky (see page 24) and Chesapeake (see page 17), was $6.8 billion for the quarter and $21.7 billion for the year. Disposal proceeds were $229 million for the quarter and $929 million for the year. In 2009, we expect our capital expenditure, excluding acquisitions and asset exchanges, to be around $20-22 billion, broadly in line with 2008, and we expect disposal proceeds to be around $2-3 billion.




·     

The quarterly dividend, to be paid in March, is 14 cents per share ($0.84 per ADS) compared with 13.525 cents per share a year ago. For the year, the dividend showed an increase of 22%. In sterling terms, the quarterly dividend is 9.818 pence per share, compared with 6.813 pence per share a year ago; for the year, the increase was 44%. During the quarter, the company did not repurchase any of its own shares for cancellation. For the year, share repurchases were 269.8 million at a cost of $2.9 billion.




(a)

Profit (loss) attributable to BP shareholders.

(b)

With effect from 1 January 2008, replacement cost profit excludes inventory holding gains and losses net of tax. Comparative amounts have been amended to the new basis. See page 2 for further details.

( c )

Comparative for the third quarter has been corrected from 29.75 pence to 27.76 pence.



The commentaries above and following are based on replacement cost profit and should be read in conjunction with the cautionary statement on page 11.



Top of page 2

Analysis of replacement cost profit and reconciliation to profit (loss) for the period

Fourth  

Third 

Fourth 

     

quarter 

quarter 

quarter 

 

Year

2007 

2008 

2008 

$ million

2008 

2007 

7,870 

12,709 

4,756 

Exploration and Production

38,308 

27,602 

(1,296)

1,972 

416 

Refining and Marketing

4,176 

2,621 

(427)

(16)

(680)

Other businesses and corporate

(1,223)

(1,209)

(267)

838 

633 

Consolidation adjustment(a)

466 

(220)

5,880 

15,503 

5,125 

RC profit before interest and tax(b)

41,727 

28,794 

           
     

Finance costs and net finance

   
     

income relating to pensions and

   

(242)

(238)

(251)

other post-retirement benefits

(956)

(741)

(2,138)

(5,099)

(2,145)

Taxation on a replacement cost basis(c)

(14,669)

(9,359)

(105)

(137)

(142)

Minority interest

(509)

(324)

     

Replacement cost profit attributable

   

3,395 

10,029 

2,587 

to BP shareholders(c)

25,593 

18,370 

           

1,427 

(2,978)

(8,788)

Inventory holding gains (losses)

(6,488)

3,558 

     

Taxation (charge) credit on inventory

   

(423)

998 

2,857 

holding gains and losses

2,052 

(1,083)

     

Profit (loss) for the period attributable

   

4,399  

8,049 

(3,344)

to BP shareholders

21,157 

20,845 



(a)

The consolidation adjustments in the third and fourth quarters of 2008 were impacted by a significant fall in prices and, in the third quarter, were also impacted by a substantial reduction in the volumes of equity crude within the refining and marketing system.

(b)

Replacement cost profit reflects the replacement cost of supplies. The replacement cost profit for the period is arrived at by excluding from profit inventory holding gains and losses and their associated tax effect. Inventory holding gains and losses, for this purpose, are calculated for all inventories except for those that are held as part of a trading position and certain other temporary inventory positions. BP uses this measure to assist investors in assessing BP’s performance from period to period. Replacement cost profit is not a recognized GAAP measure.

(c)

Effective 1 January 2008, replacement cost profit excludes inventory holding gains and losses and their associated tax effect. Previously, replacement cost profit excluded inventory gains and losses while the tax charge remained unadjusted and included the tax effect on inventory holding gains and losses. Comparative amounts have been amended to the new basis and the impact of the change is shown in the table below. There is no impact on profit for the period.



   

Fourth 

 

Year 

quarter 

$ million

2007 

2007 

     

Replacement cost profit attributable to BP shareholders

   

- as previously reported

17,287 

2,972 

- tax effect on inventory holding gains and losses

1,083 

423 

- as amended

18,370 

3,395 



Top of page 3

Non-operating items and fair value accounting effects

Non-operating items(a)

Fourth

Third 

Fourth 

     

quarter 

quarter 

quarter 

 

Year

2007 

2008 

2008 

$ million

2008 

2007 

           

(654)

1,118 

244 

Exploration and Production

(990)

491 

(1,146)

– 

(163)

Refining and Marketing

347 

(952)

(87)

(128)

(301)

Other businesses and corporate

(633)

(262)

(1,887)

990 

(220)

 

(1,276)

(723)

715 

(331)

97 

Taxation (b)

480 

350 

(1,172)

659 

(123)

 

(796)

(373)



Fair value accounting effects(c)

Fourth 

Third 

Fourth 

     

quarter 

quarter 

quarter 

 

Year

2007 

2008 

2008 

$ million

2008 

2007 

     

Exploration and Production

   
     

Unrecognized gains (losses) brought

   

234 

739 

642 

forward from previous period

107 

155 

     

Unrecognized (gains)

   

(107)

(642)

(389)

losses carried forward

(389)

(107)

     

Favourable (unfavourable) impact

   
     

relative to management’s

   

127 

97 

253 

measure of performance

(282)

48 

     

Refining and Marketing

   
     

Unrecognized gains (losses) brought

   

367 

489 

(147)

forward from previous period

429 

72 

     

Unrecognized (gains)

   

(429)

147 

82 

losses carried forward

82 

(429)

     

Favourable (unfavourable) impact

   
     

relative to management’s

   

(62)

636 

(65)

measure of performance

511 

(357)

65 

733 

188 

 

229 

(309)

(25)

(245)

(83)

Taxation (b)

(83)

111 

40 

488 

105 

 

146 

(198)



Total of non-operating items and fair value accounting effects

Fourth 

Third 

Fourth 

     

quarter 

quarter 

quarter 

 

Year

2007 

2008 

2008 

$ million

2008 

2007 

           

(527)

1,215 

497 

Exploration and Production

(1,272)

539 

(1,208)

636 

(228)

Refining and Marketing

858 

(1,309)

(87)

(128)

(301)

Other businesses and corporate

(633)

(262)

(1,822)

1,723 

(32)

 

(1,047)

(1,032)

690 

(576)

14 

Taxation (b)

397 

461 

(1,132)

1,147 

(18)

 

(650)

(571)



(a)

An analysis of non-operating items by type is provided on page 20 and a geographical analysis is shown on pages 7, 9 and 10.

(b)

Tax is calculated using the quarter’s effective tax rate on replacement cost profit . Amounts for 2007 comparative periods have been amended to reflect a redefinition of the effective tax rate on replacement cost profit arising as a result of the exclusion of tax effects on inventory holding gains and losses as described on page 2.

(c)

An explanation of fair value accounting effects is provided on page 11.



Top of page 4

Per share amounts

Fourth 

Third 

Fourth 

     

quarter 

quarter 

quarter 

 

Year

2007 

2008 

2008 

 

2008 

2007 

     

Results for the period ($ million)

   

4,399 

8,049 

(3,344)

Profit (loss)(a)

21,157 

20,845 

3,395 

10,029 

2,587 

Replacement cost profit

25,593 

18,370 

           
     

Shares outstanding at period end

   

18,932,143 

18,710,980 

18,716,098 

(thousand) (b)

18,716,098 

18,932,143 

3,155,357 

3,118,497 

3,119,350 

–     ADS equivalent (thousand) (b)

3,119,350 

3,155,357 

           
     

Average number of shares

   

18,979,138 

18,746,202 

18,713,465 

outstanding (thousand)(b)

18,789,827 

19,163,389 

3,163,190 

3,124,367 

3,118,911 

–     ADS equivalent (thousand) (b)

3,131,638 

3,193,898 

     

Shares repurchased in the

   

121,175 

92,861 

 

period (thousand)

269,757  

663,150 

           
     

Per ordinary share (cents)

   

23.15 

42.93 

(17.62)

Profit (loss) for the period

112.59 

108.76 

17.90 

53.43 

13.93 

RC profit for the period

136.20 

95.85 

           
     

Per ADS (cents)

   

138.90 

257.58 

(105.72)

Profit (loss) for the period

675.54 

652.56 

107.40 

320.58 

83.58 

RC profit for the period

817.20 

575.10 



(a)

Profit attributable to BP shareholders.

(b)

Excludes treasury shares and the shares held by the Employee Share Ownership Plans and includes certain shares that will be issuable in the future under employee share plans.



Dividends

Dividends payable

BP today announced a dividend of 14 cents per ordinary share to be paid in March. Holders of ordinary shares will receive 9.818 pence per share and holders of American Depositary Receipts (ADRs) $0.84 per ADS. The dividend is payable on 9 March 2009 to shareholders on the register on 20 February 2009. Participants in the Dividend Reinvestment Plan (DRIP) or the DRIP facility in the US Direct Access Plan will receive the dividend in the form of shares, also on 9 March 2009.

Dividends paid

Fourth 

Third 

Fourth 

   

quarter 

quarter 

quarter 

 

Year

2007 

2008 

2008 

 

2008 

2007 

     

Dividends paid per ordinary share

   

10.825 

14.000 

14.000 

     cents

55.050 

42.300 

5.308 

7.039 

8.705 

     pence

29.387 

20.995 

64.95 

84.00 

84.00 

Dividends paid per ADS (cents)

330.30 

253.80 



Top of page 5

Net debt ratio – net debt: net debt + equity

Fourth 

Third 

Fourth 

   

quarter 

quarter 

quarter 

 

Year

2007 

2008 

2008 

$ million

2008 

2007 

31,045 

28,300 

33,204 

Gross debt

33,204 

31,045 

     

Less: fair value asset (liability) of

   

666 

149 

(34)

hedges related to finance debt

(34)

666 

30,379 

28,151 

33,238 

 

33,238 

30,379 

3,562 

6,142 

8,197 

Cash and cash equivalents

8,197 

3,562 

26,817 

22,009 

25,041 

Net debt

25,041 

26,817 

94,652 

106,790 

91,549 

Equity

91,549 

94,652 

22% 

17%

21% 

Net debt ratio

21% 

22% 



Net debt and net debt ratio are non-GAAP measures. We believe that these measures provide useful information to investors. Net debt enables investors to see the economic effect of gross debt, related hedges and cash and cash equivalents in total. The net debt ratio enables investors to see how significant net debt is relative to equity from shareholders. Net debt has been redefined to include the fair value of associated derivative financial instruments that are used to hedge foreign exchange and interest rate risks relating to finance debt, for which hedge accounting is claimed. The derivatives are reported on the balance sheet within the headings ‘Derivative financial instruments’. Amounts for comparative periods are presented on a consistent basis. See Note 2(c) on page 24 for further information.
 
 

Top of page 6

Exploration and Production

Fourth 

Third 

Fourth 

   

quarter 

quarter 

quarter 

 

Year

2007 

2008 

2008 

$ million

2008 

2007 

7,950 

12,545 

4,497 

Profit before interest and tax (a)

37,915 

27,729 

(80)

164 

259 

Inventory holding (gains) losses

393 

(127)

     

Replacement cost profit before

   

7,870 

12,709 

4,756 

interest and tax

38,308 

27,602 

           
     

By region:

   

725 

2,488 

2,692 

UK

5,979 

3,585 

266 

424 

180 

Rest of Europe

1,230 

1,402 

2,240 

3,739 

1,299 

US

11,724 

7,929 

4,639 

6,058 

585 

Rest of World

19,375 

14,686 

7,870 

12,709 

4,756 

 

38,308 

27,602 



(a)

Includes profit after interest and tax of equity-accounted entities.



The replacement cost profit before interest and tax for the fourth quarter and full year was $4,756 million and $38,308 million respectively, a decrease of 40% and an increase of 39% over the same periods of 2007.

The decrease in the fourth quarter is primarily due to lower realizations and lower earnings from equity-accounted entities (primarily TNK-BP due to the effect of lagged tax reference prices, lower prices and impairment charges). This was partly offset by the impact of higher reported volumes, lower costs and a higher contribution from the gas marketing and trading business. For the full year, the increase primarily reflects higher realizations. In addition, the full-year result reflects a higher contribution from the gas marketing and trading business but was impacted by higher production taxes and higher depreciation.

The net non-operating gain of $244 million in the fourth quarter primarily comprises fair value gains on embedded derivatives partly offset by impairment charges primarily resulting from the current low price environment. The impairment charge for the quarter includes a $517 million write-down of our investment in Rosneft based on its quoted market price at the end of the year. For the full year, the net non-operating charge was $990 million with the most significant items being net impairment charges and net fair value losses on embedded derivatives, partly offset by the reversal of certain provisions. The corresponding periods in 2007 contained net non-operating losses of $654 million and net gains of $491 million respectively. Additionally, in the fourth quarter, fair value accounting effects had a favourable impact of $253 million compared with a favourable impact of $127 million a year ago. For the full year, the unfavourable effect was $282 million compared with a favourable effect of $48 million a year ago.

Reported production for the quarter was 3,945mboe/d, 1% higher than the fourth quarter of 2007. After adjusting for the impact of lower entitlement in our production-sharing agreements (PSAs), production was 4% higher than the fourth quarter of 2007.

Reported production for the full year was 3,838mboe/d, slightly higher than 2007. After adjusting for the effect of lower entitlement in our PSAs, production was 5% higher than 2007. This reflected strong performance from our existing assets, the continued ramp-up of production following the start-up of major projects in late 2007 and the start-up of a further nine major projects in 2008.

In December, we successfully started production from the third and fourth wells at the Thunder Horse field with production now at around 200,000 barrels of oil equivalent per day, signalling the completion of commissioning and commencement of full operation.

During the quarter, we announced that BP and BG Group agreed to exchange a package of North Sea assets. BP has agreed to acquire BG Group's interests in a number of Southern North Sea fields and BG Group has agreed to acquire BP's interests in three Central North Sea fields. BG Group also agreed to acquire 32% of the Chevron-operated Erskine field from BP. The deal is subject to government, regulatory and co-venturer approvals and completion is expected in the second quarter of 2009.

Also during the quarter, BP signed a PSA for an offshore block on the east coast of India – the block was offered in the 7th New Exploration Licensing Policy by the government of India.

Our 2008 reserves replacement ratio, excluding acquisitions and disposals, is expected to be more than 100% (details of which will be provided in BP Annual Report and Accounts 2008).

Top of page 7

Exploration and Production

Fourth 

Third 

Fourth 

   

quarter 

quarter 

quarter 

 

Year

2007 

2008 

2008 

$ million

2008 

2007 

           
     

Non-operating items

   

(567)

1,093 

1,506 

UK

(177)

(230)

(3)

– 

– 

Rest of Europe

535 

213 

(318)

US

(331)

369 

(297)

22 

(944)

Rest of World

(482)

(183)

(654)

1,118 

244 

 

(990)

491 

           
     

Fair value accounting effects (a)

   

(11)

11 

164 

UK

45 

 

– 

– 

Rest of Europe

– 

 

19 

136 

11 

US

(231)

(77)

119 

(50)

78 

Rest of World

(96)

124 

127 

97 

253 

 

(282)

48 

           
     

Exploration expense

   

17 

16 

UK

121 

46 

 

– 

Rest of Europe

– 

61 

59 

128 

US

306 

252 

123 

168 

94 

Rest of World

454 

458 

201 

232 

239 

 

882 

756 

           
     

Production (net of royalties) (b)

   
     

Liquids (mb/d) (net of royalties) (c)

   

199 

146 

171 

UK

173 

201 

50 

44 

45 

Rest of Europe

43 

51 

523 

473 

590 

US

538 

514 

1,697 

1,620 

1,654 

Rest of World

1,647 

1,648 

2,469 

2,283 

2,460 

 

2,401 

2,414 

           
     

Natural gas (mmcf/d) (net of royalties)

   

853 

504 

837 

UK

759 

768 

26 

23 

21 

Rest of Europe

23 

29 

2,183 

2,094 

2,243 

US

2,157 

2,174 

5,275 

5,390 

5,512 

Rest of World

5,395 

5,172 

8,337 

8,011 

8,613 

 

8,334 

8,143 

           
     

Total hydrocarbons (mboe/d) (d)

   

346 

233 

316 

UK

304 

333 

55 

47 

49 

Rest of Europe

47 

56 

900 

834 

976 

US

910 

888 

2,606 

2,550 

2,604 

Rest of World

2,577 

2,541 

3,907 

3,664 

3,945 

 

3,838 

3,818 

           
     

Average realizations (e)

   

82.72 

111.47 

52.09 

Total liquids ($/bbl)

90.20 

67.45 

4.83 

6.49 

5.08 

Natural gas ($/mcf)

6.00 

4.53 

56.03 

73.49 

40.94 

Total hydrocarbons ($/boe)

62.60 

47.18 



(a)

These effects represent the favourable (unfavourable) impact relative to management’s measure of performance. Further information on fair value accounting effects is provided on pages 3 and 11.

(b)

Includes BP’s share of production of equity-accounted entities.

(c)

Crude oil and natural gas liquids.

(d)

Natural gas is converted to oil equivalent at 5.8 billion cubic feet = 1 million barrels.

(e)

Based on sales of consolidated subsidiaries only - this excludes equity-accounted entities.

Because of rounding, some totals may not agree exactly with the sum of their component parts.



Top of page 8

Refining and Marketing

Fourth 

Third 

Fourth 

     

quarter 

quarter 

quarter 

 

Year

2007 

2008 

2008 

$ million

2008 

2007 

67 

(823)

(8,064)

Profit (loss) before interest and tax(a)

(1,884)

6,076 

(1,363)

2,795 

8,480 

Inventory holding (gains) losses(b)

6,060 

(3,455)

     

Replacement cost profit (loss)

   

(1,296)

1,972 

416 

before interest and tax

4,176 

2,621 

     

By region :

   

134 

188 

335 

UK

748 

1,048 

278 

1,045 

613 

Rest of Europe

2,716 

1,652 

(1,805)

338 

(735)

US

(644)

(1,232)

97 

401 

203 

Rest of World

1,356 

1,153 

(1,296)

1,972 

416 

 

4,176 

2,621 



(a)

Includes profit after interest and tax of equity-accounted entities.

(b)

The large inventory holding losses in the fourth quarter reflect the substantial fall in prices over the quarter.



The replacement cost profit before interest and tax for the fourth quarter and full year of 2008 was $416 million and $4,176 million respectively. The results in the equivalent periods of 2007 were a loss of $1,296 million and a profit of $2,621 million. The net impact of non-operating items was a charge of $163 million in the quarter and a gain of $347 million for the full year. A year ago, the results included net non-operating charges for the fourth quarter and full year of $1,146 million and $952 million respectively. Fair value accounting effects had an unfavourable impact of $65 million for the fourth quarter and a favourable impact of $511 million for the year. A year ago, there were unfavourable impacts of $62 million for the quarter and $357 million for the full year.
 
Compared to a year ago, despite a much weaker environment, including that relating to our petrochemicals business, we have continued to deliver improvements in our performance. The fourth-quarter result benefited from improved operational performance in our refineries, a greater supply and trading contribution, lower costs and improved marketing margins. While the global refining indicator margin (GIM) was lower than a year ago, our restored capacity allowed us to better capture the available refining margins. These improvements were partially offset by negative foreign exchange effects on in-transit crude and product cargoes, caused by the rapid strengthening of the US dollar, and by the adverse impact of prior-month pricing of domestic pipeline barrels for our US refining system.
 
For the full year, significant performance improvements in both our Fuels Value Chains and International Businesses mitigated cost inflation and, to a large extent, the much weaker environment. The main sources of improvement were from restoring the revenues of our refining operations; improved supply and trading performance; improved marketing performance, particularly from the International Businesses, and reduced costs. The cost reductions were driven by the simplification of our business structure through the establishment of Fuels Value Chains and a reduction in our geographical footprint, as well as by strong cost management. The largest environmental factors were the weaker refining margins, particularly in the US, and the adverse impacts of foreign exchange movements and the fall in crude prices, notably in the second half of 2008.

Refining throughputs for the quarter and the year were 2,032mb/d and 2,155mb/d respectively, compared to 1,998mb/d and 2,127mb/d for the same periods a year ago. Solomon availability was seven percentage points higher than the fourth quarter of 2007 and six percentage points higher for the year as a whole, the increases being driven primarily by improvements at the Texas City and Whiting refineries. During December, Ultraformer number 3 successfully restarted, completing the restoration of the economic capability of the Texas City refinery.
 
The economic environment remains challenging, with continued slowing of global economies and uncertainty in the global financial markets. In this environment, our marketing businesses anticipate continued low demand for our products. Crude oil prices have stabilized recently and in the current quarter we do not expect to see a repeat of the impact from falling prices on our US domestic pipeline barrels.
 
 

Top of page 9

Refining and Marketing

Fourth 

Third 

Fourth 

     

quarter 

quarter 

quarter 

 

Year

2007 

2008 

2008 

$ million

2008 

2007 

           
     

Non-operating items

   

(10)

(46)

UK

(96)

667 

(56)

(10)

(100)

Rest of Europe

(227)

(128)

(977)

13 

43 

US

814 

(1,181)

(103)

(12)

(60)

Rest of World

(144)

(310)

(1,146)

 

(163)

 

347 

(952)

           
     

Fair value accounting effects (a)

   

270 

97 

UK

186 

(52)

122 

(45)

Rest of Europe

54 

(110)

(32)

174 

(91)

US

231 

(165)

(36)

70 

(26)

Rest of World

40 

(30)

(62)

636 

(65)

 

511 

(357)

           
     

Refinery throughputs (mb/d)

   

 

– 

 

UK

 

67 

689 

730 

697 

Rest of Europe

739 

691 

996 

1,158 

1,063 

US

1,121 

1,064 

313 

297 

272 

Rest of World

295 

305 

1,998 

2,185 

2,032 

Total throughput

2,155 

2,127 

84.0 

87.7 

91.4 

Refining availability (%) (b)

88.8 

82.9 

           
     

Oil sales volumes (mb/d)

   
     

Refined products

   

328 

303 

302 

UK

310 

339 

1,330 

1,281 

1,262 

Rest of Europe

1,256 

1,294 

1,455 

1,453 

1,435 

US

1,460 

1,533 

680 

662 

667 

Rest of World

685 

640 

3,793 

3,699 

3,666 

Total marketing sales

3,711 

3,806 

1,696 

2,107 

1,779 

Trading/supply sales

1,987 

1,818 

5,489 

5,806 

5,445 

Total refined product sales

5,698 

5,624 

1,659 

1,511 

1,540 

Crude oil

1,689 

1,885 

7,148 

7,317 

6,985 

Total oil sales

7,387 

7,509 

           
     

Global Indicator Refining Margin ($/bbl) (c)

   

4.84 

7.13 

7.48 

NWE

6.72 

4.99 

6.82 

9.87 

2.49 

USGC

6.78 

13.48 

3.39 

10.47 

2.53 

Midwest

5.17 

12.81 

8.49 

7.07 

6.80 

USWC

7.42 

15.05 

5.80 

5.90 

5.16 

Singapore

6.30 

5.29 

5.68 

8.03 

5.20 

Average

6.50 

9.94 

           
     

Chemicals production (kte)

   

228 

144 

96 

UK

665 

967 

660 

711 

516 

Rest of Europe

2,592 

2,650 

1,088 

850 

579 

US

3,487 

4,328 

1,497 

1,358 

1,196 

Rest of World

5,683 

6,083 

3,473 

3,063 

2,387 

Total production

12,427 

14,028 



(a)

These effects represent the favourable (unfavourable) impact relative to management’s measure of performance. Further information on fair value accounting effects is provided on pages 3 and 11.

(b)

Refining availability represents Solomon Associates' operational availability, which is defined as the percentage of the year that a unit is available for processing after subtracting the annualized time lost due to turnaround activity and all planned mechanical, process and regulatory maintenance downtime.

(c)

The Global Indicator Refining Margin (GIM) is the average of regional indicator margins weighted for BP’s crude refining capacity in each region. Each regional indicator margin is based on a single representative crude with product yields characteristic of the typical level of upgrading complexity. The regional indicator margins may not be representative of the actual margins achieved by BP in any period because of BP’s particular refinery configurations and crude and product slate.



Top of page 10

Other businesses and corporate

Fourth 

Third 

Fourth 

     

quarter 

quarter 

quarter 

 

Year

2007 

2008 

2008 

$ million

2008 

2007 

(443)

(35)

(729)

Profit (loss) before interest and tax(a)

(1,258)

(1,233)

16 

19 

49 

Inventory holding (gains) losses

35 

24 

     

Replacement cost profit (loss) before

   

(427)

(16)

(680)

interest and tax

(1,223)

(1,209)

           
     

By region:

   

(87)

385 

(483)

UK

(336)

(30)

(78)

(41)

Rest of Europe

(148)

(103)

(336)

(288)

(277)

US

(902)

(960)

(9)

(35)

121 

Rest of World

163 

(116)

(427)

(16)

(680)

 

(1,223)

(1,209)

     

Results include:

   
     

Non-operating items

   

(28)

(20)

(106)

UK

(173)

(42)

(2)

(2)

(18)

Rest of Europe

(80)

15 

(57)

(105)

(115)

US

(302)

(239)

 

(1)

(62)

Rest of World

(78)

(87)

(128)

(301)

 

(633)

(262)



(a)

Includes profit after interest and tax of equity-accounted entities.



Other businesses and corporate comprises the Alternative Energy business, Shipping, the group's aluminium asset, Treasury (which includes interest income on the group's cash and cash equivalents) and corporate activities worldwide.
 
The replacement cost loss before interest and tax for the fourth quarter was $680 million, compared with a loss of $427 million a year ago. For the year, the replacement cost loss before interest and tax was $1,223 million in 2008 compared with a loss of $1,209 million a year ago.
 
The net non-operating charge was $301 million for the fourth quarter and $633 million for the full year. The fourth quarter included a net charge of $174 million for impairment, a $91 million restructuring charge, a charge of $41 million in relation to revisions to environmental and other provisions and a net $8 million gain on disposals. The prior year included net non-operating charges of $87 million in the fourth quarter and $262 million for the year.
 
In Alternative Energy,
we announced full commercial operations of phase I of the Sherbino Wind Farm in Texas. The first 150MW of the project, which has a potential capacity of 750MW, has been built through a 50:50 joint venture agreement with Padoma Wind Power LLC, a wholly owned subsidiary of NRG Energy, Inc.
 
During the fourth quarter, due to increasingly competitive market conditions, BP Solar announced plans to refocus operations to larger-scale plants to achieve lower cost manufacturing, and in November we announced the closure of our manufacturing plant in Australia.
 
The fourth-quarter reduction in solar capacity was the result of a fire in our Tata BP Solar joint venture in India.
 
In 2009, we expect quarterly charges, excluding non-operating items, for Other businesses and corporate to average in the range of $400-500 million.

 

Fourth 

Third 

Fourth 

 

quarter 

quarter 

quarter 

 

2008 

2008 

2007 

       

Wind – net rated capacity as at period end (megawatts) (a)

432 

243 

172 

Solar – cell production capacity as at period end (megawatts)(b)

213 

277 

228 



(a)

Net wind capacity is the sum of the rated capacities of the assets/turbines that have entered into commercial operation, including BP’s share of equity-accounted entities. The equivalent capacities on a gross-JV basis (which includes 100% of the capacity of equity-accounted entities where BP has partial ownership) are 785MW as at the fourth quarter of 2008, 453MW as at the third quarter of 2008 and 373MW as at the fourth quarter last year.

(b)

Solar capacity is the theoretical cell production capacity per annum of in-house manufacturing facilities.



Top of page 11

Information on fair value accounting effects

BP uses derivative instruments to manage the economic exposure relating to inventories above normal operating requirements of crude oil, natural gas and petroleum products as well as certain contracts to supply physical volumes at future dates. Under IFRS, these inventories and contracts are recorded at historic cost and on an accruals basis, respectively. The related derivative instruments, however, are required to be recorded at fair value with gains and losses recognized in income because hedge accounting is either not permitted or not followed, principally due to the impracticality of effectiveness testing requirements. Therefore, measurement differences in relation to recognition of gains and losses occur. Gains and losses on these inventories and contracts are not recognized until the commodity is sold in a subsequent accounting period. Gains and losses on the related derivative commodity contracts are recognized in the income statement from the time the derivative commodity contract is entered into on a fair value basis using forward prices consistent with the contract maturity.
 
IFRS requires that inventory held for trading be recorded at its fair value using period end spot prices whereas any related derivative commodity instruments are required to be recorded at values based on forward prices consistent with the contract maturity. Depending on market conditions, these forward prices can be either higher or lower than spot prices resulting in measurement differences.
 
BP enters into contracts for pipelines and storage capacity which, under IFRS, are recorded on an accruals basis. These contracts are risk managed using a variety of derivative instruments which are fair valued under IFRS. This results in measurement differences in relation to recognition of gains and losses.
 
The way that BP manages the economic exposures described above, and measures performance internally, differs from the way these activities are measured under IFRS. BP calculates this difference by comparing the IFRS result with management’s internal measure of performance, under which the inventory and the supply and capacity contracts in question are valued based on fair value using relevant forward prices prevailing at the end of the period. We believe that disclosing management’s estimate of this difference provides useful information for investors because it enables investors to see the economic effect of these activities as a whole. The impacts of fair value accounting effects, relative to management’s internal measure of performance, are shown in the table on page 3. Information for all quarters of 2006, 2007 and 2008 can be found at
www.bp.com/FVAE .
 
 
 
 

Cautionary statement: The foregoing discussion and the notes which follow contain forward-looking statements particularly those regarding tax rate; capital expenditure; disposal proceeds; the expected timing of completion of certain transactions; expected 2008 reserves replacement ratio; the continued slowing of global economies and uncertainty in the global financial markets; anticipated low demand for certain products; impact from falling crude oil prices on US domestic pipeline barrels; potential capacity of the Sherbino wind farm; quarterly charges and expected timing of commencement of production at the Sunrise field. By their nature, forward-looking statements involve risk and uncertainty and actual results may differ from those expressed in such statements depending on a variety of factors including the following: the timing of bringing new fields onstream; industry product supply; demand and pricing; operational problems; general economic conditions (including inflation); political stability and economic growth in relevant areas of the world; changes in laws and governmental regulations and quotas; exchange rate fluctuations; development and use of new technology; the success or otherwise of partnering; the actions of competitors; natural disasters and adverse weather conditions; changes in public expectations and other changes to business conditions; wars and acts of terrorism or sabotage; and other factors discussed in this announcement. For more information you should refer to our Annual Report and Accounts 2007 and our 2007 Annual Report on Form 20-F filed with the US Securities and Exchange Commission.


 

                  
 

      SIGNATURES


 
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
 
 
 
 

BP p.l.c.
(Registrant)
 


Dated: 03 February, 2009

/s/ D. J. PEARL
..............................
D. J. PEARL
Deputy Company Secretary