bp201607266k.htm
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 July, 2016


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
Second quarter and half year 2016(a)
 
Top of page 1
FOR IMMEDIATE RELEASE                                         London 26 July 2016
 

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
(5,823)
(583)
(1,419)
 
Profit (loss) for the period(b)
 
(2,002)
(3,221)
(443)
98
(828)
 
Inventory holding (gains) losses*, net of tax
 
(730)
(942)
(6,266)
(485)
(2,247)
 
Replacement cost profit (loss)*
 
(2,732)
(4,163)
       
Net (favourable) unfavourable
     
       
  impact of non-operating items* and fair value
     
7,579
1,017
2,967
 
  accounting effects*, net of tax
 
3,984
8,053
1,313
532
720
 
Underlying replacement cost profit*
 
1,252
3,890
       
Replacement cost profit (loss)
     
(34.25)
(2.63)
(12.03)
 
    per ordinary share (cents)
 
(14.71)
(22.77)
(2.05)
(0.16)
(0.72)
 
    per ADS (dollars)
 
(0.88)
(1.37)
       
Underlying replacement cost profit
     
7.17
2.88
3.85
 
    per ordinary share (cents)
 
6.73
21.27
0.43
0.17
0.23
 
    per ADS (dollars)
 
0.40
1.28

·  
Replacement cost (RC) loss for the second quarter was $2,247 million, compared with a loss of $6,266 million a year ago. After adjusting for a net charge for non-operating items of $2,819 million and net unfavourable fair value accounting effects of $148 million (both on a post-tax basis), underlying RC profit for the second quarter was $720 million, compared with $1,313 million for the same period in 2015. For the half year, RC loss was $2,732 million, compared with a loss of $4,163 million a year ago. After adjusting for a net charge for non-operating items of $3,597 million and net unfavourable fair value accounting effects of $387 million (both on a post-tax basis), underlying RC profit for the half year was $1,252 million, compared with $3,890 million for the same period in 2015. The lower result arises mainly due to the impact of lower oil and gas realizations on the Upstream result. Non-operating items include a restructuring charge of $68 million for the quarter and $414 million for the half year. Cumulative restructuring charges from the beginning of the fourth quarter 2014 totalled $1.9 billion by the end of the second quarter 2016.

·  
All amounts, including finance costs, relating to the Gulf of Mexico oil spill have been treated as non-operating items, with a net pre-tax charge of $5,229 million for the second quarter and $6,146 million for the half year. As announced on 14 July 2016, following significant progress in resolving outstanding claims arising from the 2010 Deepwater Horizon accident and oil spill, a reliable estimate has now been determined for all remaining material liabilities arising from the incident, and a charge has been recorded this quarter. For further information on the Gulf of Mexico oil spill and its consequences see page 9 and Note 2 on page 17. See also Legal proceedings on page 33.

·  
Net cash provided by operating activities for the second quarter and half year was $3.9 billion and $5.8 billion respectively, compared with $6.3 billion and $8.1 billion for the same periods in 2015. Excluding post-tax amounts related to the Gulf of Mexico oil spill, net cash provided by operating activities for the second quarter and half year was $5.3 billion and $8.3 billion respectively, compared with $6.4 billion and $8.9 billion for the same periods in 2015.

·  
Net debt* at 30 June 2016 was $30.9 billion, compared with $24.8 billion a year ago. The net debt ratio* at 30 June 2016 was 24.7%, compared with 18.8% a year ago. Net debt and the net debt ratio are non-GAAP measures. See page 24 for more information.

·  
Capital expenditure on an accruals basis* for the second quarter was $4.2 billion, of which organic capital expenditure* was $3.9 billion, compared with $4.7 billion for the same period in 2015, of which organic capital expenditure was $4.5 billion. For the half year, capital expenditure on an accruals basis was $8.1 billion, of which organic capital expenditure was $7.9 billion, compared with $9.1 billion for the same period in 2015, of which organic capital expenditure was $8.9 billion. See page 26 for further information.

·  
Disposal proceeds, as per the cash flow statement, were $0.4 billion for the second quarter and $1.6 billion for the half year, compared with $0.5 billion and $2.3 billion for the same periods in 2015. In addition, $0.3 billion was received in the second quarter in relation to the sale of approximately 11.5% from our shareholding in Castrol India Limited.

·  
BP today announced a quarterly dividend of 10.00 cents per ordinary share ($0.600 per ADS), which is expected to be paid on 16 September 2016. The corresponding amount in sterling will be announced on 6 September 2016. See page 23 for further information.

*
 
For items marked with an asterisk throughout this document, definitions are provided in the Glossary on page 30.
(a)
This results announcement also represents BP’s half-year financial report (see page 10).
(b)
Profit attributable to BP shareholders.


The commentaries above and following should be read in conjunction with the cautionary statement on page 35.


 
Top of page 2
Group headlines (continued)
 

·  
The effective tax rate (ETR) on RC loss for the second quarter and half year was 51% and 49% respectively, compared with 33% and 47% for the same periods in 2015. Further to recording a charge for all remaining material liabilities relating to the Gulf of Mexico oil spill, the overall tax position was reviewed and the tax credit for the quarter reflects tax on the charge taken and other positive tax adjustments, all of which have been treated as non-operating items. Adjusting for non-operating items, fair value accounting effects and a one-off adjustment as a result of the reduction in the rate of the UK North Sea supplementary charge in the first quarter 2015, the underlying ETR in the second quarter and half year was 21% and 20% respectively, compared with 35% and 28% for the same periods in 2015. The underlying ETR for the half year is lower than a year ago mainly due to changes in the mix of profits and foreign exchange effects.


Top of page 3
Analysis of RC profit (loss) before interest and tax
and reconciliation to profit (loss) for the period
 

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
       
RC profit (loss) before interest and tax*
     
228
(1,205)
(109)
 
    Upstream
 
(1,314)
600
1,628
1,880
1,405
 
    Downstream
 
3,285
3,711
510
66
246
 
    Rosneft
 
312
693
(11,202)
(1,074)
(5,525)
 
    Other businesses and corporate(a)
 
(6,599)
(11,833)
(39)
40
(121)
 
    Consolidation adjustment – UPII*
 
(81)
(168)
(8,875)
(293)
(4,104)
 
RC profit (loss) before interest and tax
 
(4,397)
(6,997)
       
Finance costs and net finance expense relating to
     
(364)
(440)
(460)
 
  pensions and other post-retirement benefits
 
(900)
(722)
3,013
273
2,346
 
Taxation on a RC basis
 
2,619
3,645
(40)
(25)
(29)
 
Non-controlling interests
 
(54)
(89)
(6,266)
(485)
(2,247)
 
RC profit (loss) attributable to BP shareholders
 
(2,732)
(4,163)
627
(132)
1,188
 
Inventory holding gains (losses)
 
1,056
1,383
       
Taxation (charge) credit on inventory holding
     
(184)
34
(360)
 
  gains and losses
 
(326)
(441)
       
Profit (loss) for the period attributable to
     
(5,823)
(583)
(1,419)
 
  BP shareholders
 
(2,002)
(3,221)

(a)
Includes costs related to the Gulf of Mexico oil spill. See page 9 and also Note 2 on page 17 for further information on the accounting for the Gulf of Mexico oil spill.


Analysis of underlying RC profit before interest and tax
 

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
       
Underlying RC profit before interest and tax*
     
494
(747)
29
 
    Upstream
 
(718)
1,098
1,867
1,813
1,513
 
    Downstream
 
3,326
4,025
510
66
246
 
    Rosneft
 
312
693
(401)
(178)
(376)
 
    Other businesses and corporate
 
(554)
(691)
(39)
40
(121)
 
    Consolidation adjustment – UPII
 
(81)
(168)
2,431
994
1,291
 
Underlying RC profit before interest and tax
 
2,285
4,957
       
Finance costs and net finance expense relating to
     
(356)
(317)
(337)
 
  pensions and other post-retirement benefits
 
(654)
(705)
(722)
(120)
(205)
 
Taxation on an underlying RC basis
 
(325)
(273)
(40)
(25)
(29)
 
Non-controlling interests
 
(54)
(89)
1,313
532
720
 
Underlying RC profit attributable to BP shareholders
 
1,252
3,890

Reconciliations of underlying RC profit or loss to the nearest equivalent IFRS measure are provided on page 1 for the group and on pages 4-9 for the segments.


Top of page 4
Upstream
 

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
225
(1,236)
(24)
 
Profit (loss) before interest and tax
 
(1,260)
615
3
31
(85)
 
Inventory holding (gains) losses*
 
(54)
(15)
228
(1,205)
(109)
 
RC profit (loss) before interest and tax
 
(1,314)
600
       
Net (favourable) unfavourable impact
     
       
  of non-operating items* and
     
266
458
138
 
  fair value accounting effects*
 
596
498
494
(747)
29
 
Underlying RC profit (loss) before interest and tax*(a)
 
(718)
1,098

(a)
See page 5 for a reconciliation to segment RC profit before interest and tax by region.

Financial results

The replacement cost loss before interest and tax for the second quarter and half year was $109 million and $1,314 million respectively, compared with a profit of $228 million and $600 million for the same periods in 2015. The second quarter and half year included a net non-operating gain of $7 million and a charge of $348 million respectively, compared with a net non-operating charge of $236 million and $478 million for the same periods a year ago. Fair value accounting effects in the second quarter and half year had an unfavourable impact of $145 million and $248 million respectively, compared with an unfavourable impact of $30 million and $20 million in the same periods of 2015.

After adjusting for non-operating items and fair value accounting effects, the underlying replacement cost result before interest and tax for the second quarter and half year was a profit of $29 million and a loss of $718 million respectively, compared with a profit of $494 million and $1,098 million for the same periods in 2015. The result for the second quarter and half year reflected lower liquids and gas realizations partly offset by lower costs reflecting the benefits of simplification and efficiency activities, lower rig cancellation costs, lower exploration write-offs, and lower depreciation, depletion and amortization expense.

Production

Production for the quarter was 2,090mboe/d, 1.0% lower than the second quarter of 2015. Underlying production* for the quarter increased by 1.5% mainly due to lower seasonal turnaround activity. For the first half, production was 2,259mboe/d, 2.3% higher than in the same period of 2015. First-half underlying production was broadly flat compared to first half 2015.

Key events

On 16 May BP announced it has doubled its interest in the Culzean development in the UK Central North Sea to 32%, following its acquisition of an additional interest from JX Nippon.

On 24 May BP and the State Oil Company of the Republic of Azerbaijan signed a memorandum of understanding to jointly explore potential prospects in Block D230 in the North Absheron basin in the Azerbaijan sector of the Caspian Sea.

On 25 May BP announced the start-up of a major water injection project at its Thunder Horse platform in the US Gulf of Mexico. The project will increase recovery of oil and natural gas from one of the field’s three main reservoirs.

On 9 June BP announced a gas discovery from the Baltim SW-1 exploration well in the Baltim South Development lease (BP 50% and Eni 50%, operator) in the East Nile Delta.

On 10 June BP and Det norske oljeselskap announced the creation of Aker BP ASA, an independent oil and gas company. Under the terms of the proposed transaction, the BP Norge and Det norske businesses will combine and be renamed Aker BP ASA which will be independently operated and listed on the Oslo Stock Exchange. Aker BP will be owned by current Det norske shareholder Aker (40%), other Det norske shareholders (30%) and BP (30%).

On 17 June BP and Rosneft signed final binding agreements, subject to regulatory approval, to create a new joint venture, Yermak Neftegaz LLC (Rosneft 51% and BP 49%). The joint venture will conduct onshore exploration within two Areas of Mutual Interest (AMIs) in the West Siberian and Yenisey-Khatanga basins in the Russian Federation, which cover a combined area of about 260,000 square kilometres.

On 20 June BP announced that together with the Egyptian Natural Gas Holding Company (EGAS), it has sanctioned development of the Atoll Phase One project, an early production scheme that will bring gas to the Egyptian domestic market, due to start in the first half of 2018. BP has a 100% interest in the concession.

In July BP, on behalf of Tangguh production-sharing agreement* (PSA) partners, announced the final investment decision has been approved for the development of the Tangguh expansion project in the Papua Barat province of Indonesia. The project will add a third LNG process train (Train 3), two offshore platforms, 13 new production wells, an expanded LNG loading facility, and supporting infrastructure.

This builds on the progress announced in our first-quarter results, which comprised the following: BP acquired interests in exploration licences in the Flemish Pass Basin offshore of Newfoundland, Canada; BP was awarded acreage in Norway at


Top of page 5
Upstream
 

Skarv with partners Statoil, PGNiG and E.ON; BP and Oman Oil signed a heads of agreement with the government of the Sultanate of Oman, in relation to block 61; In Salah Gas, a Sonatrach, BP and Statoil joint venture, started up its Southern Fields project in Algeria; an exploration discovery was announced on the Nooros East prospect in Egypt, by the operator Eni who has tied it back for production; BP signed a framework agreement with Kuwait Petroleum Corporation to enhance recovery of existing oil and gas resources and explore possible other joint opportunities; BP and China National Petroleum Corporation signed a PSA for shale gas exploration, development and production in China; BP completed evaluation of the
Kepler 3 discovery in the Gulf of Mexico with the aim to start production later this year; the Point Thomson project in Alaska, US, began production.

Outlook

Looking ahead, we expect third-quarter reported production to be lower than the second quarter due to seasonal turnaround and maintenance activities and the impact of the plant outage at the Enterprise Pascagoula gas processing plant in the Gulf of Mexico. 

The commentary above contains forward-looking statements and should be read in conjunction with the cautionary statement on page 35.


 
Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
       
Underlying RC profit (loss) before interest and tax
     
(66)
(667)
(305)
 
US
 
(972)
(611)
560
(80)
334
 
Non-US
 
254
1,709
494
(747)
29
     
(718)
1,098
       
Non-operating items
     
(135)
(163)
(57)
 
US
 
(220)
(203)
(101)
(192)
64
 
Non-US
 
(128)
(275)
(236)
(355)
7
     
(348)
(478)
       
Fair value accounting effects
     
(55)
(33)
(57)
 
US
 
(90)
(58)
25
(70)
(88)
 
Non-US
 
(158)
38
(30)
(103)
(145)
     
(248)
(20)
       
RC profit (loss) before interest and tax
     
(256)
(863)
(419)
 
US
 
(1,282)
(872)
484
(342)
310
 
Non-US
 
(32)
1,472
228
(1,205)
(109)
     
(1,314)
600
       
Exploration expense
     
194
112
48
 
US
 
160
272
708
142
302
 
Non-US(a)
 
444
802
902
254
350
     
604
1,074
806
161
260
 
Of which: Exploration expenditure written off(a)
 
421
898
       
Production (net of royalties)(b)
     
       
Liquids* (mb/d)
     
334
403
401
 
US
 
402
362
147
128
117
 
Europe
 
122
130
631
878
584
 
Rest of World
 
731
692
1,111
1,409
1,102
     
1,255
1,184
       
Natural gas (mmcf/d)
     
1,477
1,603
1,666
 
US
 
1,634
1,497
281
289
238
 
Europe
 
263
273
4,046
4,019
3,829
 
Rest of World
 
3,924
4,176
5,805
5,910
5,733
     
5,822
5,945
       
Total hydrocarbons* (mboe/d)
     
588
679
688
 
US
 
684
621
196
178
158
 
Europe
 
168
177
1,328
1,571
1,244
 
Rest of World
 
1,408
1,412
2,112
2,428
2,090
     
2,259
2,209
       
Average realizations*(c)
     
56.69
26.97
44.99
 
Total liquids(d) ($/bbl)
 
34.63
51.49
3.80
2.84
2.66
 
Natural gas ($/mcf)
 
2.75
4.12
40.04
22.57
30.63
 
Total hydrocarbons ($/boe)
 
26.24
38.47

(a)
Second quarter and first half 2015 include a $432-million write-off in Libya.
(b)
Includes BP’s share of production of equity-accounted entities in the Upstream segment.
(c)
Realizations are based on sales by consolidated subsidiaries only – this excludes equity-accounted entities.
(d)
Includes condensate, natural gas liquids and bitumen.
 
Because of rounding, some totals may not agree exactly with the sum of their component parts.


Top of page 6
Downstream
 

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
2,234
1,783
2,463
 
Profit (loss) before interest and tax
 
4,246
5,017
(606)
97
(1,058)
 
Inventory holding (gains) losses*
 
(961)
(1,306)
1,628
1,880
1,405
 
RC profit before interest and tax
 
3,285
3,711
       
Net (favourable) unfavourable impact
     
       
  of non-operating items* and
     
239
(67)
108
 
  fair value accounting effects*
 
41
314
1,867
1,813
1,513
 
Underlying RC profit before interest and tax*(a)
 
3,326
4,025

(a)
See page 7 for a reconciliation to segment RC profit before interest and tax by region and by business.

Financial results

The replacement cost profit before interest and tax for the second quarter and first half was $1,405 million and $3,285 million respectively, compared with $1,628 million and $3,711 million for the same periods in 2015.

The 2016 results include a net non-operating charge of $37 million for the second quarter and a net non-operating gain of $249 million for the half year, compared with a net non-operating charge of $122 million and $85 million for the same periods in 2015 (see pages 7 and 27 for further information on non-operating items). Fair value accounting effects had unfavourable impacts of $71 million for the second quarter and $290 million for the half year, compared with unfavourable impacts of $117 million and $229 million in the same periods of 2015.

After adjusting for non-operating items and fair value accounting effects, the underlying replacement cost profit before interest and tax for the second quarter and half year was $1,513 million and $3,326 million respectively, compared with $1,867 million and $4,025 million for the same periods in 2015.

Replacement cost profit before interest and tax for the fuels, lubricants and petrochemicals businesses is set out on page 7.

Fuels business

The fuels business reported an underlying replacement cost profit before interest and tax of $1,011 million for the second quarter and $2,327 million for the half year, compared with $1,394 million and $3,190 million for the same periods in 2015. The results for the quarter and half year reflect a significantly weaker refining environment, partially offset by lower costs from simplification and efficiency programmes, increased fuels marketing performance and strong refining operations. The half-year result was also impacted by a lower contribution from supply and trading, particularly in the first quarter.

During the first quarter of 2016 we completed the divestment of several non-strategic midstream assets in the US and Europe.

Lubricants business

The lubricants business reported an underlying replacement cost profit before interest and tax of $412 million for the quarter and $796 million for the half year, compared with $397 million and $742 million for the same periods in 2015. The quarter and half-year results reflect continued strong performance in growth markets and premium brands and lower costs from simplification and efficiency programmes. These factors contributed to a growth of more than 10% in the half-year underlying replacement cost profit before interest and tax, which was partially offset by adverse foreign exchange impacts.

During the second quarter of 2016 we sold approximately 11.5% from our 71% shareholding in Castrol India Limited.

Petrochemicals business

The petrochemicals business reported an underlying replacement cost profit before interest and tax of $90 million for the second quarter and $203 million for the half year, compared with $76 million and $93 million for the same periods in 2015. The result for the half year reflects stronger operations and margin optimization in a petrochemicals environment similar to the same period in 2015.

During the first quarter of 2016 we completed the sale of our Decatur petrochemicals complex in Alabama, US.

Outlook

In the third quarter we expect turnaround activity to remain high, at a similar level to the second quarter, and that industry refining margins will continue to be under significant pressure.



The commentary above contains forward-looking statements and should be read in conjunction with the cautionary statement on page 35.


Top of page 7
Downstream
 

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
       
Underlying RC profit before interest and tax -  region
     
       
  by region
     
576
540
386
 
US
 
926
1,237
1,291
1,273
1,127
 
Non-US
 
2,400
2,788
1,867
1,813
1,513
     
3,326
4,025
       
Non-operating items
     
63
113
17
 
US
 
130
59
(185)
173
(54)
 
Non-US
 
119
(144)
(122)
286
(37)
     
249
(85)
       
Fair value accounting effects
     
(48)
(87)
(78)
 
US
 
(165)
(175)
(69)
(132)
7
 
Non-US
 
(125)
(54)
(117)
(219)
(71)
     
(290)
(229)
       
RC profit before interest and tax
     
591
566
325
 
US
 
891
1,121
1,037
1,314
1,080
 
Non-US
 
2,394
2,590
1,628
1,880
1,405
     
3,285
3,711
       
Underlying RC profit before interest and tax - 
     
       
  by business(a)(b)
     
1,394
1,316
1,011
 
Fuels
 
2,327
3,190
397
384
412
 
Lubricants
 
796
742
76
113
90
 
Petrochemicals
 
203
93
1,867
1,813
1,513
     
3,326
4,025
       
Non-operating items and fair value
     
       
  accounting effects(c)
     
(152)
55
(93)
 
Fuels
 
(38)
(212)
(87)
(1)
(3)
 
Lubricants
 
(4)
(101)
13
(12)
 
Petrochemicals
 
1
(1)
(239)
67
(108)
     
(41)
(314)
       
RC profit before interest and tax(a)(b)
     
1,242
1,371
918
 
Fuels
 
2,289
2,978
310
383
409
 
Lubricants
 
792
641
76
126
78
 
Petrochemicals
 
204
92
1,628
1,880
1,405
     
3,285
3,711
               
19.4
10.5
13.8
 
BP average refining marker margin (RMM)* ($/bbl)
 
12.2
17.3
       
Refinery throughputs (mb/d)
     
622
699
668
 
US
 
683
623
810
807
805
 
Europe
 
806
807
224
238
231
 
Rest of World
 
235
274
1,656
1,744
1,704
     
1,724
1,704
94.0
95.0
95.7
 
Refining availability* (%)
 
95.3
94.1
       
Marketing sales of refined products (mb/d)
     
1,145
1,071
1,115
 
US
 
1,093
1,122
1,160
1,144
1,170
 
Europe
 
1,157
1,167
465
488
515
 
Rest of World(d)
 
502
479
2,770
2,703
2,800
     
2,752
2,768
2,753
2,810
2,875
 
Trading/supply sales of refined products(d)
 
2,843
2,706
5,523
5,513
5,675
 
Total sales volumes of refined products
 
5,595
5,474
       
Petrochemicals production (kte)
     
946
896
558
 
US
 
1,454
1,851
852
992
909
 
Europe
 
1,901
1,824
1,898
1,909
1,967
 
Rest of World
 
3,876
3,561
3,696
3,797
3,434
     
7,231
7,236

(a)
Segment-level overhead expenses are included in the fuels business result.
(b)
BP’s share of income from petrochemicals at our Gelsenkirchen and Mülheim sites in Germany is reported in the fuels business.
(c)
For Downstream, fair value accounting effects arise solely in the fuels business.
(d)
Comparative periods in 2015 include a minor reclassification between Marketing sales in Rest of World and Trading/supply sales of refined products.


Top of page 8
Rosneft
 

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016(a)
 
$ million
 
2016(a)
2015
534
62
291
 
Profit before interest and tax(b)
 
353
755
(24)
4
(45)
 
Inventory holding (gains) losses*
 
(41)
(62)
510
66
246
 
RC profit before interest and tax
 
312
693
 
Net charge (credit) for non-operating items*
 
510
66
246
 
Underlying RC profit before interest and tax*
 
312
693

Replacement cost profit before interest and tax and underlying replacement cost profit before interest and tax for the second quarter and half year was $246 million and $312 million respectively, compared with $510 million and $693 million for the same periods in 2015. There were no non-operating items in the second quarter and half year of either year.

Compared with the same period last year, the result for the second quarter was primarily affected by lower oil prices. For the half year, the result was primarily affected by lower oil prices, partially offset by favourable foreign exchange effects.

BP’s two nominees, Bob Dudley and Guillermo Quintero, were re-elected to Rosneft’s board by the annual general meeting (AGM) on 15 June. The AGM also adopted a resolution to pay dividends of 11.75 roubles per ordinary share. BP expects to receive a dividend in relation to the 2015 annual results of approximately $335 million, after the deduction of withholding tax and subject to fluctuations in foreign exchange.


Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016(a)
     
2016(a)
2015
       
Production (net of royalties) (BP share)
     
815
808
812
 
Liquids* (mb/d)
 
810
815
1,172
1,282
1,266
 
Natural gas (mmcf/d)
 
1,274
1,198
1,017
1,029
1,030
 
Total hydrocarbons* (mboe/d)
 
1,029
1,022

(a)
The operational and financial information of the Rosneft segment for the second quarter and first half of the year is based on preliminary operational and financial results of Rosneft for the six months ended 30 June 2016. Actual results may differ from these amounts.
(b)
The Rosneft segment result includes equity-accounted earnings arising from BP’s 19.75% shareholding in Rosneft as adjusted for the accounting required under IFRS relating to BP’s purchase of its interest in Rosneft and the amortization of the deferred gain relating to the disposal of BP’s interest in TNK-BP. These adjustments have increased the reported profit before interest and tax for the second quarter and first half 2016, as shown in the table above, compared with the equivalent amount in Russian roubles that we expect Rosneft to report in its own financial statements under IFRS. BP’s share of Rosneft’s profit before interest and tax for each year-to-date period is calculated by translating the amounts reported in Russian roubles into US dollars using the average exchange rate for the year to date. BP's share of Rosneft’s earnings after finance costs, taxation and non-controlling interests, as adjusted, is included in the BP group income statement within profit before interest and taxation.


The commentary above contains forward-looking statements and should be read in conjunction with the cautionary statement on page 35.


Top of page 9
Other businesses and corporate
 

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
       
Profit (loss) before interest and tax
     
(10,747)
(794)
(5,106)
 
Gulf of Mexico oil spill
 
(5,900)
(11,070)
(455)
(280)
(419)
 
Other
 
(699)
(763)
(11,202)
(1,074)
(5,525)
 
Profit (loss) before interest and tax
 
(6,599)
(11,833)
 
Inventory holding (gains) losses*
 
(11,202)
(1,074)
(5,525)
 
RC profit (loss) before interest and tax
 
(6,599)
(11,833)
       
Net charge (credit) for non-operating items*
     
10,747
794
5,106
 
Gulf of Mexico oil spill
 
5,900
11,070
54
102
43
 
Other
 
145
72
10,801
896
5,149
 
Net charge (credit) for non-operating items
 
6,045
11,142
(401)
(178)
(376)
 
Underlying RC profit (loss) before interest and tax*
 
(554)
(691)
       
Underlying RC profit (loss) beforeinterest and tax
     
(144)
(110)
(109)
 
US
 
(219)
(206)
(257)
(68)
(267)
 
Non-US
 
(335)
(485)
(401)
(178)
(376)
     
(554)
(691)
       
Non-operating items
     
(10,757)
(848)
(5,136)
 
US
 
(5,984)
(11,081)
(44)
(48)
(13)
 
Non-US
 
(61)
(61)
(10,801)
(896)
(5,149)
     
(6,045)
(11,142)
       
RC profit (loss) before interest and tax
     
(10,901)
(958)
(5,245)
 
US
 
(6,203)
(11,287)
(301)
(116)
(280)
 
Non-US
 
(396)
(546)
(11,202)
(1,074)
(5,525)
     
(6,599)
(11,833)

Other businesses and corporate comprises biofuels and wind businesses, shipping, treasury (which includes interest income on the group's cash and cash equivalents), corporate activities including centralized functions, and the costs of the Gulf of Mexico oil spill.

Financial results

The replacement cost loss before interest and tax for the second quarter and half year was $5,525 million and $6,599 million respectively, compared with $11,202 million and $11,833 million for the same periods in 2015.

The second-quarter result included a net non-operating charge of $5,149 million, primarily relating to costs for the Gulf of Mexico oil spill, compared with a net charge of $10,801 million a year ago. Following significant progress in resolving outstanding claims, a reliable estimate has now been determined for all remaining material liabilities associated with the incident. The second-quarter charge reflects the recognition of additional provisions for these claims, including the cost of all remaining business economic loss claims under the 2012 Plaintiffs’ Steering Committee (PSC) settlement and the cost of resolving economic loss and property damage claims from individuals and businesses that either opted out of the PSC settlement and/or were excluded from that settlement. The second-quarter 2015 charge reflected a $9.8-billion charge associated with the settlement agreements signed in July 2015. For further information see Note 2 on page 17. For the half year, the net non-operating charge was $6,045 million, compared with a net non-operating charge of $11,142 million a year ago.

After adjusting for non-operating items, the underlying replacement cost loss before interest and tax for the second quarter and half year was $376 million and $554 million respectively, compared with $401 million and $691 million for the same periods in 2015. The half-year result reflects lower corporate costs and favourable foreign exchange impacts.

Gulf of Mexico oil spill

As previously disclosed, on 4 April 2016 the federal district court approved the Consent Decree between the United States, the Gulf states and BP which resolves all United States and Gulf states’ natural resource damages claims and Clean Water Act penalty claims, and certain other claims.

For further information see Note 2 on page 17 and Legal proceedings on page 33.

Biofuels

The net ethanol-equivalent production (which includes ethanol and sugar) for the second quarter was 283 million litres, compared with 247 million litres for the same period 2015.

Wind

Net wind generation capacity*(a) was 1,477MW at 30 June 2016 compared with 1,588MW at 30 June 2015. BP’s net share of wind generation for the second quarter and half year was 1,060GWh and 2,407GWh respectively, compared with 1,150GWh and 2,277GWh for the same periods in 2015.

(a)
Capacity figures include 23MW in the Netherlands managed by our Downstream segment at 30 June 2016, and 32MW at 30 June 2015.


Top of page 10
Half-yearly financial report
 

This results announcement also represents BP’s half-yearly financial report for the purposes of the Disclosure and Transparency Rules made by the UK Financial Conduct Authority. In this context: (i) the condensed set of financial statements can be found on pages 12-25; (ii) pages 1-9, and 26-35 comprise the interim management report; and (iii) the directors’ responsibility statement and auditors’ independent review report can be found on pages 10-11.


Statement of directors’ responsibilities
 

The directors confirm that, to the best of their knowledge, the condensed set of financial statements on pages 12-25 has been prepared in accordance with IAS 34 ‘Interim Financial Reporting’, and that the interim management report on pages 1-9 and 26-35 includes a fair review of the information required by the Disclosure and Transparency Rules.

The directors of BP p.l.c. are listed on pages 56-59 of BP Annual Report and Form 20-F 2015, with the exception of Antony Burgmans and Phuthuma Nhleko who retired at the 2016 Annual General Meeting.
 
By order of the board

Bob Dudley
Brian Gilvary
Group Chief Executive
Chief Financial Officer
25 July 2016
25 July 2016


Top of page 11
Independent review report to BP p.l.c.
 

We have been engaged by the company to review the condensed set of financial statements in the half-yearly financial report for the six months ended 30 June 2016 which comprises the group income statement, group statement of comprehensive income, group statement of changes in equity, group balance sheet, condensed group cash flow statement, and Notes 1 to 11. We have read the other information contained in the half-yearly financial report and considered whether it contains any apparent misstatements or material inconsistencies with the information in the condensed set of financial statements.

This report is made solely to the company in accordance with guidance contained in International Standard on Review Engagements 2410 (UK and Ireland), ‘Review of Interim Financial Information Performed by the Independent Auditor of the Entity’ issued by the Auditing Practices Board for use in the United Kingdom (ISRE 2410). To the fullest extent permitted by law, we do not accept or assume responsibility to anyone other than the company, for our work, for this report, or for the conclusions we have formed.

Directors’ responsibilities

The half-yearly financial report is the responsibility of, and has been approved by, the directors. The directors are responsible for preparing the half-yearly financial report in accordance with the Disclosure and Transparency Rules of the United Kingdom’s Financial Conduct Authority.

As disclosed in Note 1, the annual financial statements of the group are prepared in accordance with International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB) and IFRS as adopted by the European Union (EU). The condensed set of financial statements included in this half-yearly financial report has been prepared in accordance with International Accounting Standard 34, ‘Interim Financial Reporting’, as issued by the IASB and as adopted by the EU.

Our responsibility

Our responsibility is to express to the company a conclusion on the condensed set of financial statements in the half-yearly financial report based on our review.

Scope of review

We conducted our review in accordance with ISRE 2410. A review of interim financial information consists of making enquiries, primarily of persons responsible for financial and accounting matters, and applying analytical and other review procedures. A review is substantially less in scope than an audit conducted in accordance with International Standards on Auditing (UK and Ireland) and consequently does not enable us to obtain assurance that we would become aware of all significant matters that might be identified in an audit. Accordingly, we do not express an audit opinion.

Conclusion

Based on our review, nothing has come to our attention that causes us to believe that the condensed set of financial statements in the half-yearly financial report for the six months ended 30 June 2016 is not prepared, in all material respects, in accordance with International Accounting Standard 34 as issued by the IASB and as adopted by the EU and the Disclosure and Transparency Rules of the United Kingdom’s Financial Conduct Authority.


Ernst & Young LLP
London
25 July 2016

The maintenance and integrity of the BP p.l.c. website are the responsibility of the directors; the review work carried out by the auditors does not involve consideration of these matters and, accordingly, the auditors accept no responsibility for any changes that may have occurred to the financial information since it was initially presented on the website.

Legislation in the United Kingdom governing the preparation and dissemination of financial statements may differ from legislation in other jurisdictions.


Top of page 12
Financial statements
 

Group income statement

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
               
62,051
38,512
46,442
 
Sales and other operating revenues (Note 5)
 
84,954
117,570
156
29
274
 
Earnings from joint ventures – after interest and tax
 
303
260
670
142
380
 
Earnings from associates – after interest and tax
 
522
1,032
195
145
101
 
Interest and other income
 
246
315
133
338
79
 
Gains on sale of businesses and fixed assets
 
417
271
63,205
39,166
47,276
 
Total revenues and other income
 
86,442
119,448
46,153
26,603
32,752
 
Purchases
 
59,355
85,412
17,185
6,519
10,446
 
Production and manufacturing expenses(a)
 
16,965
24,185
173
14
258
 
Production and similar taxes (Note 6)
 
272
535
3,765
3,730
3,637
 
Depreciation, depletion and amortization
 
7,367
7,601
       
Impairment and losses on sale of businesses and
     
286
13
52
 
  fixed assets
 
65
483
902
254
350
 
Exploration expense
 
604
1,074
2,989
2,458
2,697
 
Distribution and administration expenses
 
5,155
5,772
(8,248)
(425)
(2,916)
 
Profit (loss) before interest and taxation
 
(3,341)
(5,614)
289
394
414
 
Finance costs(a)
 
808
570
       
Net finance expense relating to pensions and other
     
75
46
46
 
  post-retirement benefits
 
92
152
(8,612)
(865)
(3,376)
 
Profit (loss) before taxation
 
(4,241)
(6,336)
(2,829)
(307)
(1,986)
 
Taxation(a)
 
(2,293)
(3,204)
(5,783)
(558)
(1,390)
 
Profit (loss) for the period
 
(1,948)
(3,132)
       
Attributable to
     
(5,823)
(583)
(1,419)
 
  BP shareholders
 
(2,002)
(3,221)
40
25
29
 
  Non-controlling interests
 
54
89
(5,783)
(558)
(1,390)
     
(1,948)
(3,132)
               
       
Earnings per share (Note 7)
     
       
Profit (loss) for the period attributable to
     
       
  BP shareholders
     
       
  Per ordinary share (cents)
     
(31.83)
(3.16)
(7.60)
 
    Basic
 
(10.78)
(17.62)
(31.83)
(3.16)
(7.60)
 
    Diluted
 
(10.78)
(17.62)
       
  Per ADS (dollars)
     
(1.91)
(0.19)
(0.46)
 
    Basic
 
(0.65)
(1.06)
(1.91)
(0.19)
(0.46)
 
    Diluted
 
(0.65)
(1.06)

(a)
See Note 2 for information on the impact of the Gulf of Mexico oil spill on these income statement line items.


Top of page 13
Financial statements (continued)
 

Group statement of comprehensive income

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
               
(5,783)
(558)
(1,390)
 
Profit (loss) for the period
 
(1,948)
(3,132)
       
Other comprehensive income
     
       
Items that may be reclassified subsequently to profit
     
       
  or loss
     
698
874
(35)
 
  Currency translation differences
 
839
(914)
       
  Exchange gains (losses) on translation of foreign
     
       
    operations reclassified to gain or loss on sale of
     
16
6
 
    businesses and fixed assets
 
6
16
1
 
  Available-for-sale investments
 
1
128
(62)
(289)
 
  Cash flow hedges marked to market
 
(351)
(84)
       
  Cash flow hedges reclassified to the income
     
81
23
16
 
    statement
 
39
155
4
13
6
 
  Cash flow hedges reclassified to the balance sheet
 
19
9
       
  Share of items relating to equity-accounted entities,
     
329
290
197
 
    net of tax
 
487
249
(92)
(86)
80
 
  Income tax relating to items that may be reclassified
 
(6)
32
1,165
1,058
(25)
     
1,033
(536)
       
Items that will not be reclassified to profit or loss
     
       
  Remeasurements of the net pension and other
     
2,688
(1,222)
(1,763)
 
    post-retirement benefit liability or asset
 
(2,985)
2,120
       
  Income tax relating to items that will not be
     
(754)
402
592
 
    reclassified
 
994
(596)
1,934
(820)
(1,171)
     
(1,991)
1,524
3,099
238
(1,196)
 
Other comprehensive income
 
(958)
988
(2,684)
(320)
(2,586)
 
Total comprehensive income
 
(2,906)
(2,144)
       
Attributable to
     
(2,732)
(351)
(2,604)
 
  BP shareholders
 
(2,955)
(2,219)
48
31
18
 
  Non-controlling interests
 
49
75
(2,684)
(320)
(2,586)
     
(2,906)
(2,144)


Top of page 14
 
Financial statements (continued)
 

Group statement of changes in equity

   
BP
   
   
shareholders’
Non-controlling
Total
$ million
 
equity
interests
equity
         
At 1 January 2016
 
97,216
1,171
98,387
         
Total comprehensive income
 
(2,955)
49
(2,906)
Dividends
 
(2,268)
(52)
(2,320)
Share-based payments, net of tax
 
447
447
Share of equity-accounted entities’ change in equity, net of tax
 
65
65
Transactions involving non-controlling interests
 
221
214
435
At 30 June 2016
 
92,726
1,382
94,108
         
   
BP
   
   
shareholders’
Non-controlling
Total
$ million
 
equity
interests
equity
         
At 1 January 2015
 
111,441
1,201
112,642
         
Total comprehensive income
 
(2,219)
75
(2,144)
Dividends
 
(3,400)
(42)
(3,442)
Share-based payments, net of tax
 
300
300
Share of equity-accounted entities’ change in equity, net of tax
 
(3)
(3)
Transactions involving non-controlling interests
 
(2)
(2)
At 30 June 2015
 
106,119
1,232
107,351


Top of page 15
 
Financial statements (continued)
 

Group balance sheet

   
30 June
31 December
$ million
 
2016
2015
Non-current assets
     
Property, plant and equipment
 
125,946
129,758
Goodwill
 
11,288
11,627
Intangible assets
 
18,444
18,660
Investments in joint ventures
 
8,324
8,412
Investments in associates
 
11,221
9,422
Other investments
 
1,002
1,002
Fixed assets
 
176,225
178,881
Loans
 
500
529
Trade and other receivables
 
2,193
2,216
Derivative financial instruments
 
5,286
4,409
Prepayments
 
1,020
1,003
Deferred tax assets
 
4,573
1,545
Defined benefit pension plan surpluses
 
774
2,647
   
190,571
191,230
Current assets
     
Loans
 
242
272
Inventories
 
16,398
14,142
Trade and other receivables
 
22,672
22,323
Derivative financial instruments
 
2,934
4,242
Prepayments
 
1,941
1,838
Current tax receivable
 
374
599
Other investments
 
107
219
Cash and cash equivalents
 
23,517
26,389
   
68,185
70,024
Assets classified as held for sale (Note 3)
 
4,380
578
   
72,565
70,602
Total assets
 
263,136
261,832
Current liabilities
     
Trade and other payables
 
36,561
31,949
Derivative financial instruments
 
2,139
3,239
Accruals
 
4,918
6,261
Finance debt
 
5,120
6,944
Current tax payable
 
1,310
1,080
Provisions
 
5,637
5,154
   
55,685
54,627
Liabilities directly associated with assets classified as held for sale (Note 3)
 
2,525
97
   
58,210
54,724
Non-current liabilities
     
Other payables
 
13,870
2,910
Derivative financial instruments
 
4,268
4,283
Accruals
 
502
890
Finance debt
 
50,607
46,224
Deferred tax liabilities
 
7,797
9,599
Provisions
 
23,693
35,960
Defined benefit pension plan and other post-retirement benefit plan deficits
 
10,081
8,855
   
110,818
108,721
Total liabilities
 
169,028
163,445
Net assets
 
94,108
98,387
Equity
     
BP shareholders’ equity
 
92,726
97,216
Non-controlling interests
 
1,382
1,171
Total equity
 
94,108
98,387


Top of page 16
Financial statements (continued)
 

Condensed group cash flow statement

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
       
Operating activities
     
(8,612)
(865)
(3,376)
 
Profit (loss) before taxation
 
(4,241)
(6,336)
       
Adjustments to reconcile profit (loss) before taxation
     
       
  to net cash provided by operating activities
     
       
  Depreciation, depletion and amortization and
     
4,571
3,891
3,897
 
    exploration expenditure written off
 
7,788
8,499
       
  Impairment and (gain) loss on sale of businesses
     
153
(325)
(27)
 
    and fixed assets
 
(352)
212
       
  Earnings from equity-accounted entities,
     
(654)
(24)
(485)
 
    less dividends received
 
(509)
(930)
       
  Net charge for interest and other finance
     
13
168
113
 
    expense less net interest paid
 
281
142
255
259
204
 
  Share-based payments
 
463
17
       
  Net operating charge for pensions and other post-
     
       
    retirement benefits, less contributions and
     
(30)
32
(56)
 
    benefit payments for unfunded plans
 
(24)
(87)
10,700
735
4,565
 
  Net charge for provisions, less payments
 
5,300
11,088
       
  Movements in inventories and other current and
     
492
(1,727)
(863)
 
    non-current assets and liabilities
 
(2,590)
(3,366)
(602)
(272)
(89)
 
  Income taxes paid
 
(361)
(1,095)
6,286
1,872
3,883
 
Net cash provided by operating activities
 
5,755
8,144
       
Investing activities
     
(4,529)
(4,381)
(4,283)
 
Capital expenditure
 
(8,664)
(9,165)
(54)
(4)
(8)
 
Investment in joint ventures
 
(12)
(123)
(218)
(93)
(196)
 
Investment in associates
 
(289)
(305)
308
238
153
 
Proceeds from disposal of fixed assets
 
391
961
       
Proceeds from disposal of businesses, net of
     
224
911
291
 
  cash disposed
 
1,202
1,311
45
46
6
 
Proceeds from loan repayments
 
52
48
(4,224)
(3,283)
(4,037)
 
Net cash used in investing activities
 
(7,320)
(7,273)
       
Financing activities
     
83
2,738
2,710
 
Proceeds from long-term financing
 
5,448
7,871
(542)
(3,559)
(1,318)
 
Repayments of long-term financing
 
(4,877)
(2,849)
(13)
(112)
300
 
Net increase (decrease) in short-term debt
 
188
712
70
368
 
Net increase (decrease) in non-controlling interests
 
438
(1,691)
(1,099)
(1,169)
 
Dividends paid
– BP shareholders
 
(2,268)
(3,400)
(30)
(9)
(43)
   
– non-controlling interests
 
(52)
(42)
(2,193)
(1,971)
848
 
Net cash provided by (used in) financing activities
 
(1,123)
2,292
       
Currency translation differences relating to cash
     
286
42
(226)
 
  and cash equivalents
 
(184)
(337)
155
(3,340)
468
 
Increase (decrease) in cash and cash equivalents
 
(2,872)
2,826
32,434
26,389
23,049
 
Cash and cash equivalents at beginning of period
 
26,389
29,763
32,589
23,049
23,517
 
Cash and cash equivalents at end of period
 
23,517
32,589


Top of page 17
 
Financial statements (continued)
 

Notes

1.      Basis of preparation

The interim financial information included in this report has been prepared in accordance with IAS 34 ‘Interim Financial Reporting’.

The results for the interim periods are unaudited and, in the opinion of management, include all adjustments necessary for a fair presentation of the results for each period. All such adjustments are of a normal recurring nature. This report should be read in conjunction with the consolidated financial statements and related notes for the year ended 31 December 2015 included in the BP Annual Report and Form 20-F 2015.

The directors have made an assessment of the group’s ability to continue as a going concern and consider it appropriate to adopt the going concern basis of accounting in preparing these interim financial statements.

BP prepares its consolidated financial statements included within BP Annual Report and Form 20-F on the basis of International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB), IFRS as adopted by the European Union (EU) and in accordance with the provisions of the UK Companies Act 2006. IFRS as adopted by the EU differs in certain respects from IFRS as issued by the IASB. The differences have no impact on the group’s consolidated financial statements for the periods presented.

The financial information presented herein has been prepared in accordance with the accounting policies expected to be used in preparing BP Annual Report and Form 20-F 2016, which do not differ significantly from those used in BP Annual Report and Form 20-F 2015.

In BP Annual Report and Form 20-F 2015 we disclosed a significant estimate or judgement relating to provisions arising from the Gulf of Mexico oil spill in 2010. At that time, no reliable estimate could be made of any business economic loss (BEL) claims under the Plaintiffs’ Steering Committee (PSC) settlement that were not yet processed or processed but not yet paid, except where an eligibility notice had been issued and was not subject to appeal by BP within the Deepwater Horizon Court Supervised Settlement Program claims facility (DHCSSP). A reliable estimate could also not be made in relation to securities-related litigation and other litigation, including economic loss and property damage claims from parties excluded from and/or who opted out of the PSC settlement. No amounts were provided for these items and they were disclosed as contingent liabilities.

As a result of developments during the second quarter of 2016 sufficient information now exists in order to make a reliable estimate of the amounts that BP will pay relating to all outstanding BEL claims under the DHCSSP, securities class actions and economic loss and property damage claims from parties who were excluded from and/or opted out of the PSC settlement. Liabilities have therefore been recognized in the financial statements for these items. See Note 2 for further information.


2.      Gulf of Mexico oil spill

(a) Overview

The information presented in this note should be read in conjunction with BP Annual Report and Form 20-F 2015 – Financial statements – Note 2 and Legal proceedings on page 237 and on page 33 of this report.

Following significant progress in resolving outstanding claims arising from the 2010 Deepwater Horizon accident and oil spill, a reliable estimate has now been determined for all remaining material liabilities arising from the incident, and an additional charge has been recorded this quarter.

The group income statement includes a pre-tax charge of $5,229 million for the second quarter and $6,146 million for the first half 2016 in relation to the Gulf of Mexico oil spill. The cumulative pre-tax income statement charge since the incident, in April 2010, amounts to $61,597 million. It is now possible to reliably estimate the cost of resolving all outstanding business economic loss claims under the Plaintiffs’ Steering Committee (PSC) settlement and the cost of resolving economic loss and property damage claims from individuals and businesses that either opted out of the PSC settlement and/or were excluded from that settlement. The second-quarter increase in provisions of $4,935 million is primarily attributable to the recognition of additional provisions for these claims. The remainder of the income statement charge for the second quarter relates predominantly to the cost of the securities claims settlement with the certified class of post-explosion ADS purchasers, which was agreed in June 2016 and recognized in Other payables, and finance costs relating to the unwinding of discounting effects. The charge for the half year also includes charges recorded in the first quarter for increases in provisions for certain business economic loss claims under the PSC settlement and the settlement of certain civil claims outside of the PSC settlement and additional finance costs.


Top of page 18
Financial statements (continued)
 

Notes

2.      Gulf of Mexico oil spill (continued)

The amounts set out below reflect the impacts on the financial statements of the Gulf of Mexico oil spill for the periods presented. The income statement, balance sheet and cash flow statement impacts are included within the relevant line items in those statements as set out below.

 
Second
First
Second
     
First
First
 
quarter
quarter
quarter
     
half
half
 
2015
2016
2016
 
$ million
 
2016
2015
         
Income statement
     
 
10,747
794
5,106
 
Production and manufacturing expenses
 
5,900
11,070
 
(10,747)
(794)
(5,106)
 
Profit (loss) before interest and taxation
 
(5,900)
(11,070)
 
8
123
123
 
Finance costs
 
246
17
 
(10,755)
(917)
(5,229)
 
Profit (loss) before taxation
 
(6,146)
(11,087)
 
3,601
251
2,533
 
Taxation
 
2,784
3,713
 
(7,154)
(666)
(2,696)
 
Profit (loss) for the period
 
(3,362)
(7,374)

Further to recording a charge for all remaining material liabilities relating to the Gulf of Mexico oil spill, the overall tax position was reviewed and the tax credit for the quarter reflects tax on the charge taken and other positive tax adjustments.

     
30 June
31 December
 
$ million
 
2016
2015
 
Balance sheet
     
 
Current assets
     
 
  Trade and other receivables
 
359
686
 
  Prepayments
 
5
 
Current liabilities
     
 
  Trade and other payables
 
(2,813)
(693)
 
  Accruals
 
(40)
 
  Provisions
 
(3,427)
(3,076)
 
Net current assets (liabilities)
 
(5,876)
(3,123)
 
Non-current assets
     
 
  Deferred tax assets
 
7,771
 
Non-current liabilities
     
 
  Other payables
 
(13,268)
(2,057)
 
  Accruals
 
(186)
 
  Provisions
 
(3,063)
(13,431)
 
  Deferred tax
 
5,200
 
Net non-current assets (liabilities)
 
(8,560)
(10,474)
 
Net assets (liabilities)
 
(14,436)
(13,597)


Top of page 19
 
Financial statements (continued)
 

Notes

2.      Gulf of Mexico oil spill (continued)

 
Second
First
Second
     
First
First
 
quarter
quarter
quarter
     
half
half
 
2015
2016
2016
 
$ million
 
2016
2015
         
Cash flow statement - Operating activities
     
 
(10,755)
(917)
(5,229)
 
Profit (loss) before taxation
 
(6,146)
(11,087)
         
Adjustments to reconcile profit (loss)
     
         
  before taxation to net cash provided by
     
         
  operating activities
     
         
Net charge for interest and other finance
     
 
8
123
123
 
  expense, less net interest paid
 
246
17
 
10,607
757
4,466
 
Net charge for provisions, less payments
 
5,223
10,834
         
Movements in inventories and other current
     
 
34
(1,088)
(971)
 
  and non-current assets and liabilities
 
(2,059)
(561)
 
(106)
(1,125)
(1,611)
 
Pre-tax cash flows
 
(2,736)
(797)

Net cash from operating activities relating to the Gulf of Mexico oil spill, on a post-tax basis, amounted to an outflow of $1,398 million and an outflow of $2,523 million in the second quarter and first half of 2016 respectively. For the same periods in 2015, the amounts were an outflow of $106 million and an outflow of $797 million respectively.

Trust fund

During the first half of 2016, the remaining cash in the Deepwater Horizon Oil Spill Trust (the Trust) was exhausted and BP commenced paying claims and other costs previously funded from the Trust. For certain costs, these payments are made by BP into a qualified settlement fund, the fund then distributes the amounts to the claimant; $860 million was paid into a qualified settlement fund during the second quarter ($1,399 million during the first half).



Top of page 20
Financial statements (continued)
 

Notes

2.      Gulf of Mexico oil spill (continued)

(b) Provisions and contingent liabilities

Provisions

BP had recorded provisions relating to the Gulf of Mexico oil spill in relation to environmental expenditure, litigation and claims, and Clean Water Act penalties. Movements in the second quarter, all of which relate to litigation and claims provisions, are presented in the table below.

         
         
 
$ million 
 
Total
 
At 1 April 2016
 
2,869
 
Net increase (decrease) in provision
 
4,935
 
Utilization
– paid by BP
 
(469)
 
 
– paid by settlement fund or Trust
 
(845)
 
At 30 June 2016
 
6,490
 
Of which
– current
 
3,427
 
 
– non-current
 
3,063

Movements in each class of provision during the first half are presented in the table below.

         
Litigation
Clean
 
         
and
Water Act
 
       
Environmental
claims
penalties
Total
 
$ million 
         
 
At 1 January 2016
 
5,919
6,459
4,129
16,507
 
Net increase (decrease) in provision
 
5,715
5,715
 
Unwinding of discount
 
52
25
38
115
 
Reclassified to Other payables
 
(5,970)
(3,741)
(4,167)
(13,878)
 
Utilization
– paid by BP
 
(1)
(491)
(492)
   
– paid by settlement fund or
         
   
    Trust
 
(1,477)
(1,477)
 
At 30 June 2016
 
6,490
6,490

Environmental
The environmental provisions relating to natural resource damage costs and the early restoration framework agreement were reclassified to Other payables during the first quarter following approval by the Court in April 2016 of the Consent Decree between the United States, the Gulf states and BP. Remaining amounts related to early restoration were paid during the second quarter.

Litigation and claims
The litigation and claims provision includes amounts for the future cost of resolving claims by individuals and businesses for damage to real or personal property, lost profits or impairment of earning capacity and loss of subsistence use of natural resources. Claims administration costs and legal costs have also been provided for.

At 31 December 2015, the litigation and claims provision included amounts provided under the state claims settlement agreement with the Gulf states in relation to state claims that had not yet been paid. These amounts were reclassified to Other payables during the first quarter and are payable over 18 years; $0.9 billion was paid in July 2016.

Litigation and claims – PSC settlement
BP has provided for its best estimate of the cost associated with the 2012 PSC settlement.

Prior to the second quarter of 2016, no reliable estimate could be made of any business economic loss claims not yet processed or processed but not yet paid, except where an eligibility notice had been issued and was not subject to appeal by BP within the DHCSSP.


 
Top of page 21
 
Financial statements (continued)
 

Notes
2.      Gulf of Mexico oil spill (continued)

The DHCSSP continues to process business economic loss claims and, for certain lower-value claims, simplified processing procedures have been implemented by the DHCSSP. In recent quarters the pace of processing claims has accelerated and, by the end of the second quarter, over three quarters of the total claims had been determined. Furthermore, the number of claims that had been processed using specialized frameworks for particular industry groups, that include the application of the revised policy for matching revenue and expenses, had increased significantly. Additional insight has also been obtained into the population of undetermined claims, including the industry groupings they fall within, which enhances BP’s understanding of the claims yet to be determined. The combination of these factors provides sufficient information to reliably estimate the liability for the remaining business economic loss claims. Accordingly, a provision has been established for these items as at 30 June 2016. Amounts to settle these claims are expected to be paid by 2019.

The provision has been determined based upon an expected value of the remaining business economic loss claims. Claims are determined by the DHCSSP in accordance with the PSC settlement agreement. The amounts ultimately payable may differ from the amount provided.

Litigation and claims – Other claims
During the second quarter, significant progress was also made in resolving economic loss and property damage claims from individuals and businesses that either opted out of the PSC settlement and/or were excluded from that settlement. On 14 July 2016 the federal district court issued an order, details of which are described in Legal proceedings on page 33. Following this court order, the vast majority of these claims have now been either resolved or dismissed. Therefore, an estimate of the cost of the remaining claims, most of which is expected to be paid by the end of 2016, is also recognized in provisions.

Clean Water Act penalties
The provision previously recognized for penalties under Section 311 of the Clean Water Act, as determined by the civil settlement with the United States, was reclassified to Other payables during the first quarter following approval by the Court of the Consent Decree. The amount is payable in instalments over 15 years, commencing April 2017. The unpaid balance of this penalty accrues interest at a fixed rate.

Further information on provisions is provided in BP Annual Report and Form 20-F 2015 – Financial statements – Note 2.

Contingent liabilities

Any further outstanding Deepwater Horizon related claims are not expected to have a material impact on the group’s financial performance.


3.      Non-current assets held for sale

On 15 January 2016 BP and Rosneft announced that they had signed definitive agreements to dissolve the German refining joint operation Ruhr Oel GmbH (ROG). The restructuring, which is expected to be completed in 2016, will result in Rosneft taking ownership of ROG’s interests in the Bayernoil, MiRO Karlsruhe and PCK Schwedt refineries. In exchange, BP will take sole ownership of the Gelsenkirchen refinery and the solvent production facility DHC Solvent Chemie. Assets and associated liabilities relating to BP’s share of ROG’s interests in the Bayernoil, MiRO Karlsruhe and PCK Schwedt refineries are classified as held for sale in the group balance sheet.

On 10 June 2016 BP and Det norske oljeselskap announced the creation of Aker BP ASA, an independent oil and gas company. Under the terms of the proposed transaction, which is expected to be completed in 2016, the BP Norge AS and Det norske businesses will combine and be renamed Aker BP ASA. The transaction will result in Aker BP ASA being owned by current Det norske shareholder Aker (40%), other Det norske shareholders (30%) and BP (30%). Assets and associated liabilities relating to BP Norge AS are classified as held for sale in the group balance sheet at 30 June 2016.


Top of page 22
Financial statements (continued)
 

Notes

4.      Analysis of replacement cost profit (loss) before interest and tax and
         reconciliation to profit (loss) before taxation

 
Second
First
Second
     
First
First
 
quarter
quarter
quarter
     
half
half
 
2015
2016
2016
 
$ million
 
2016
2015
 
228
(1,205)
(109)
 
Upstream
 
(1,314)
600
 
1,628
1,880
1,405
 
Downstream
 
3,285
3,711
 
510
66
246
 
Rosneft
 
312
693
 
(11,202)
(1,074)
(5,525)
 
Other businesses and corporate(a)
 
(6,599)
(11,833)
 
(8,836)
(333)
(3,983)
     
(4,316)
(6,829)
 
(39)
40
(121)
 
Consolidation adjustment – UPII*
 
(81)
(168)
 
(8,875)
(293)
(4,104)
 
RC profit (loss) before interest and tax*
 
(4,397)
(6,997)
         
Inventory holding gains (losses)*
     
 
(3)
(31)
85
 
  Upstream
 
54
15
 
606
(97)
1,058
 
  Downstream
 
961
1,306
 
24
(4)
45
 
  Rosneft (net of tax)
 
41
62
 
(8,248)
(425)
(2,916)
 
Profit (loss) before interest and tax
 
(3,341)
(5,614)
 
289
394
414
 
Finance costs
 
808
570
         
Net finance expense relating to pensions
     
 
75
46
46
 
  and other post-retirement benefits
 
92
152
 
(8,612)
(865)
(3,376)
 
Profit (loss) before taxation
 
(4,241)
(6,336)
                 
         
RC profit (loss) before interest and tax
     
 
(10,641)
(1,256)
(5,394)
 
US
 
(6,650)
(11,138)
 
1,766
963
1,290
 
Non-US
 
2,253
4,141
 
(8,875)
(293)
(4,104)
     
(4,397)
(6,997)

(a)
Includes costs related to the Gulf of Mexico oil spill. See Note 2 for further information.


5.      Sales and other operating revenues

 
Second
First
Second
     
First
First
 
quarter
quarter
quarter
     
half
half
 
2015
2016
2016
 
$ million
 
2016
2015
         
By segment
     
 
11,036
7,431
8,176
 
Upstream
 
15,607
22,666
 
56,737
34,552
42,809
 
Downstream
 
77,361
106,185
 
512
396
422
 
Other businesses and corporate
 
818
940
 
68,285
42,379
51,407
     
93,786
129,791
                 
         
Less: sales and other operating revenues
     
         
  between segments
     
 
5,590
3,633
4,301
 
Upstream
 
7,934
11,153
 
402
118
475
 
Downstream
 
593
578
 
242
116
189
 
Other businesses and corporate
 
305
490
 
6,234
3,867
4,965
     
8,832
12,221
                 
         
Third party sales and other operating revenues
     
 
5,446
3,798
3,875
 
Upstream
 
7,673
11,513
 
56,335
34,434
42,334
 
Downstream
 
76,768
105,607
 
270
280
233
 
Other businesses and corporate
 
513
450
 
62,051
38,512
46,442
 
Total sales and other operating revenues
 
84,954
117,570
                 
         
By geographical area
     
 
21,824
13,576
17,701
 
US
 
31,277
40,665
 
44,535
27,146
32,482
 
Non-US
 
59,628
84,546
 
66,359
40,722
50,183
     
90,905
125,211
         
Less: sales and other operating revenues
     
 
4,308
2,210
3,741
 
  between areas
 
5,951
7,641
 
62,051
38,512
46,442
     
84,954
117,570


Top of page 23
Financial statements (continued)
 

Notes
 
6.      Production and similar taxes

 
Second
First
Second
     
First
First
 
quarter
quarter
quarter
     
half
half
 
2015
2016
2016
 
$ million
 
2016
2015
 
33
18
67
 
US
 
85
67
 
140
(4)
191
 
Non-US
 
187
468
 
173
14
258
     
272
535

 
7.      Earnings per share and shares in issue
 
Basic earnings per ordinary share (EpS) amounts are calculated by dividing the profit for the period attributable to ordinary shareholders by the weighted average number of ordinary shares outstanding during the period.

The calculation of EpS is performed separately for each discrete quarterly period, and for the year-to-date period. As a result, the sum of the discrete quarterly EpS amounts in any particular year-to-date period may not be equal to the EpS amount for the year-to-date period.

For the diluted EpS calculation the weighted average number of shares outstanding during the period is adjusted for the number of shares that are potentially issuable in connection with employee share-based payment plans using the treasury stock method.

 
Second
First
Second
     
First
First
 
quarter
quarter
quarter
     
half
half
 
2015
2016
2016
 
$ million
 
2016
2015
         
Results for the period
     
         
Profit (loss) for the period
     
 
(5,823)
(583)
(1,419)
 
  attributable to BP shareholders
 
(2,002)
(3,221)
 
1
1
 
Less: preference dividend
 
1
1
         
Profit (loss) attributable to BP
     
 
(5,824)
(583)
(1,420)
 
  ordinary shareholders
 
(2,003)
(3,222)
                 
         
Number of shares (thousand)(a)(b)
     
         
Basic weighted average number of
     
 
18,299,877
18,468,632
18,685,199
 
  shares outstanding
 
18,577,135
18,287,176
 
3,049,979
3,078,105
3,114,200
 
ADS equivalent
 
3,096,189
3,047,862
                 
         
Weighted average number of shares
     
         
  outstanding used to calculate
     
 
18,299,877
18,468,632
18,685,199
 
  diluted earnings per share
 
18,577,135
18,287,176
 
3,049,979
3,078,105
3,114,200
 
ADS equivalent
 
3,096,189
3,047,862
                 
 
18,318,924
18,635,861
18,777,156
 
Shares in issue at period-end
 
18,777,156
18,318,924
 
3,053,154
3,105,976
3,129,526
 
ADS equivalent
 
3,129,526
3,053,154

(a)
Excludes treasury shares and includes certain shares that will be issued in the future under employee share-based payment plans.
(b)
If the inclusion of potentially issuable shares would decrease loss per share, the potentially issuable shares are excluded from the weighted average number of shares outstanding used to calculate diluted earnings per share.

 
8.      Dividends
 
Dividends payable

BP today announced an interim dividend of 10.00 cents per ordinary share which is expected to be paid on 16 September 2016 to shareholders and American Depositary Share (ADS) holders on the register on 5 August 2016. The corresponding amount in sterling is due to be announced on 6 September 2016, calculated based on the average of the market exchange rates for the four dealing days commencing on 31 August 2016. Holders of ADSs are expected to receive $0.600 per ADS (less applicable fees). A scrip dividend alternative is available, allowing shareholders to elect to receive their dividend in the form of new ordinary shares and ADS holders in the form of new ADSs. Details of the second-quarter dividend and timetable are available at bp.com/dividends and details of the scrip dividend programme are available at bp.com/scrip.


Top of page 24
Financial statements (continued)
 

Notes
 
 
8.      Dividends (continued)
 
 
Second
First
Second
     
First
First
 
quarter
quarter
quarter
     
half
half
 
2015
2016
2016
     
2016
2015
         
Dividends paid per ordinary share
     
 
10.000
10.000
10.000
 
  cents
 
20.000
20.000
 
6.530
7.012
6.917
 
  pence
 
13.929
13.200
 
60.00
60.00
60.00
 
Dividends paid per ADS (cents)
 
120.00
120.00
         
Scrip dividends
     
 
18.9
154.4
134.4
 
Number of shares issued (millions)
 
288.8
34.6
 
134
739
695
 
Value of shares issued ($ million)
 
1,434
243

 
9.      Net debt*
 
Net debt ratio*

 
Second
First
Second
     
First
First
 
quarter
quarter
quarter
     
half
half
 
2015
2016
2016
 
$ million
 
2016
2015
 
57,104
54,012
55,727
 
Gross debt
 
55,727
57,104
         
Fair value (asset) liability of hedges related
     
 
315
(967)
(1,279)
 
  to finance debt(a)
 
(1,279)
315
 
57,419
53,045
54,448
     
54,448
57,419
 
32,589
23,049
23,517
 
Less: cash and cash equivalents
 
23,517
32,589
 
24,830
29,996
30,931
 
Net debt
 
30,931
24,830
 
107,351
97,289
94,108
 
Equity
 
94,108
107,351
 
18.8%
23.6%
24.7%
 
Net debt ratio
 
24.7%
18.8%

Analysis of changes in net debt

 
Second
First
Second
     
First
First
 
quarter
quarter
quarter
     
half
half
 
2015
2016
2016
 
$ million
 
2016
2015
         
Opening balance
     
 
57,731
53,168
54,012
 
Finance debt
 
53,168
52,854
         
Fair value (asset) liability of hedges related to
     
 
(174)
379
(967)
 
  finance debt(a)
 
379
(445)
 
32,434
26,389
23,049
 
Less: cash and cash equivalents
 
26,389
29,763
 
25,123
27,158
29,996
 
Opening net debt
 
27,158
22,646
         
Closing balance
     
 
57,104
54,012
55,727
 
Finance debt
 
55,727
57,104
         
Fair value (asset) liability of hedges related to
     
 
315
(967)
(1,279)
 
  finance debt(a)
 
(1,279)
315
 
32,589
23,049
23,517
 
Less: cash and cash equivalents
 
23,517
32,589
 
24,830
29,996
30,931
 
Closing net debt
 
30,931
24,830
 
293
(2,838)
(935)
 
Decrease (increase) in net debt
 
(3,773)
(2,184)
         
Movement in cash and cash equivalents
     
 
(131)
(3,382)
694
 
  (excluding exchange adjustments)
 
(2,688)
3,163
         
Net cash outflow (inflow) from financing
     
 
472
933
(1,692)
 
  (excluding share capital and dividends)
 
(759)
(5,734)
 
(1)
359
36
 
Other movements
 
395
10
 
340
(2,090)
(962)
 
Movement in net debt before exchange effects
 
(3,052)
(2,561)
 
(47)
(748)
27
 
Exchange adjustments
 
(721)
377
 
293
(2,838)
(935)
 
Decrease (increase) in net debt
 
(3,773)
(2,184)

(a)
Derivative financial instruments entered into for the purpose of managing interest rate and foreign currency exchange risk associated with net debt with a fair value liability position of $1,440 million (first quarter 2016 liability of $1,225 million and second quarter 2015 liability of $1,357 million) are not included in the calculation of net debt shown above as hedge accounting is not applied for these instruments.


Top of page 25
Financial statements (continued)
 

Notes
 
10.    Inventory valuation
 
A provision of $689 million was held at 30 June 2016 ($677 million at 31 March 2016 and $590 million at 30 June 2015) to write inventories down to their net realizable value. The net movement charged to the income statement during the second quarter 2016 was $12 million (first quarter 2016 was a credit of $616 million and second quarter 2015 was a credit of $210 million).

 
11.    Statutory accounts
 
The financial information shown in this publication, which was approved by the Board of Directors on 25 July 2016, is unaudited and does not constitute statutory financial statements. BP Annual Report and Form 20-F 2015 has been filed with the Registrar of Companies in England and Wales. The report of the auditor on those accounts was unqualified and did not contain a statement under section 498(2) or section 498(3) of the UK Companies Act 2006.


Top of page 26
 
Additional information
 

Capital expenditure on an accruals basis*(a)

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
       
Capital expenditure on an accruals basis
     
4,492
3,944
3,919
 
Organic capital expenditure*
 
7,863
8,929
159
276
 
Inorganic capital expenditure*
 
276
159
4,651
3,944
4,195
     
8,139
9,088


Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
       
Organic capital expenditure by segment
     
       
Upstream
     
991
1,060
754
 
US
 
1,814
2,098
2,962
2,583
2,699
 
Non-US
 
5,282
5,858
3,953
3,643
3,453
     
7,096
7,956
       
Downstream
     
190
110
191
 
US
 
301
335
290
155
237
 
Non-US
 
392
489
480
265
428
     
693
824
       
Other businesses and corporate
     
6
1
12
 
US
 
13
22
53
35
26
 
Non-US
 
61
127
59
36
38
     
74
149
4,492
3,944
3,919
     
7,863
8,929
       
Organic capital expenditure by geographical area
     
1,187
1,171
957
 
US
 
2,128
2,455
3,305
2,773
2,962
 
Non-US
 
5,735
6,474
4,492
3,944
3,919
     
7,863
8,929

(a)
The definitions of Capital expenditure on an accruals basis and Inorganic capital expenditure have been revised to exclude asset exchanges as they are non-cash transactions. Previously reported amounts have been amended with no significant impact on the comparative periods shown. Previously reported amounts for Organic capital expenditure are unchanged.

Reconciliation of additions to non-current assets to capital expenditure on an accruals basis

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
5,297
3,935
3,993
 
Additions to non-current assets(a)
 
7,928
9,566
9
6
12
 
  Additions to other investments
 
18
11
       
  Element of business combinations not related to
     
1
 
    non-current assets
 
17
(649)
54
190
 
  (Additions to) reductions in decommissioning asset
 
244
(471)
(7)
(51)
 
  Asset exchanges
 
(51)
(35)
4,651
3,944
4,195
 
Capital expenditure on an accruals basis
 
8,139
9,088

(a)
Includes additions to property, plant and equipment; goodwill; intangible assets; investments in joint ventures; and investments in associates.


Top of page 27
 
Additional information (continued)
 

Non-operating items*

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
       
Upstream
     
       
Impairment and gain (loss) on sale of businesses
     
(194)
4
 
  and fixed assets
 
4
(307)
 
Environmental and other provisions
 
11
(67)
(263)
(3)
 
Restructuring, integration and rationalization costs
 
(266)
(248)
21
13
28
 
Fair value gain (loss) on embedded derivatives
 
41
62
4
(109)
(18)
 
Other(a)
 
(127)
4
(236)
(355)
7
     
(348)
(478)
       
Downstream
     
       
Impairment and gain (loss) on sale of businesses
     
68
321
23
 
  and fixed assets
 
344
134
(7)
(3)
 
Environmental and other provisions
 
(3)
(7)
(182)
(35)
(54)
 
Restructuring, integration and rationalization costs
 
(89)
(210)
 
Fair value gain (loss) on embedded derivatives
 
(1)
(3)
 
Other
 
(3)
(2)
(122)
286
(37)
     
249
(85)
       
Rosneft
     
       
Impairment and gain (loss) on sale of businesses
     
 
  and fixed assets
 
 
Environmental and other provisions
 
 
Restructuring, integration and rationalization costs
 
 
Fair value gain (loss) on embedded derivatives
 
 
Other
 
     
       
Other businesses and corporate
     
       
Impairment and gain (loss) on sale of businesses
     
(27)
4
 
  and fixed assets
 
4
(39)
(4)
(35)
 
Environmental and other provisions
 
(35)
(4)
(23)
(48)
(11)
 
Restructuring, integration and rationalization costs
 
(59)
(29)
 
Fair value gain (loss) on embedded derivatives
 
(10,747)
(794)
(5,106)
 
Gulf of Mexico oil spill(b)
 
(5,900)
(11,070)
(54)
(1)
 
Other
 
(55)
(10,801)
(896)
(5,149)
     
(6,045)
(11,142)
(11,159)
(965)
(5,179)
 
Total before interest and taxation
 
(6,144)
(11,705)
(8)
(123)
(123)
 
Finance costs(b)
 
(246)
(17)
(11,167)
(1,088)
(5,302)
 
Total before taxation
 
(6,390)
(11,722)
3,681
310
2,483
 
Taxation credit (charge)
 
2,793
3,823
(7,486)
(778)
(2,819)
 
Total after taxation for period
 
(3,597)
(7,899)

(a)
First quarter and first half 2016 principally relate to BP’s share of impairment losses recognized by equity-accounted entities.
(b)
See Note 2 for further details regarding costs relating to the Gulf of Mexico oil spill.


Top of page 28
 
Additional information (continued)
 

Non-GAAP information on fair value accounting effects

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
       
Favourable (unfavourable) impact relative to
     
       
  management’s measure of performance
     
(30)
(103)
(145)
 
Upstream
 
(248)
(20)
(117)
(219)
(71)
 
Downstream
 
(290)
(229)
(147)
(322)
(216)
     
(538)
(249)
54
83
68
 
Taxation credit (charge)
 
151
95
(93)
(239)
(148)
     
(387)
(154)

BP uses derivative instruments to manage the economic exposure relating to inventories above normal operating requirements of crude oil, natural gas and petroleum products. Under IFRS, these inventories are recorded at historical cost. 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 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.

BP enters into commodity contracts to meet certain business requirements, such as the purchase of crude for a refinery or the sale of BP’s gas production. Under IFRS these contracts are treated as derivatives and are required to be fair valued when they are managed as part of a larger portfolio of similar transactions. Gains and losses arising are recognized in the income statement from the time the derivative commodity contract is entered into.

IFRS requires that inventory held for trading is 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, oil and gas processing and liquefied natural gas (LNG) that, 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 for consolidated entities by comparing the IFRS result with management’s internal measure of performance. Under management’s internal measure of performance the inventory and capacity contracts in question are valued based on fair value using relevant forward prices prevailing at the end of the period, the fair values of certain derivative instruments used to risk manage LNG and oil and gas contracts are deferred to match with the underlying exposure and the commodity contracts for business requirements are accounted for on an accruals basis. 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 above. A reconciliation to GAAP information is set out below.

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
 
$ million
 
2016
2015
       
Upstream
     
       
Replacement cost profit (loss) before interest and
     
258
(1,102)
36
 
  tax adjusted for fair value accounting effects
 
(1,066)
620
(30)
(103)
(145)
 
Impact of fair value accounting effects
 
(248)
(20)
228
(1,205)
(109)
 
Replacement cost profit before interest and tax
 
(1,314)
600
       
Downstream
     
       
Replacement cost profit before interest and
     
1,745
2,099
1,476
 
  tax adjusted for fair value accounting effects
 
3,575
3,940
(117)
(219)
(71)
 
Impact of fair value accounting effects
 
(290)
(229)
1,628
1,880
1,405
 
Replacement cost profit before interest and tax
 
3,285
3,711
       
Total group
     
       
Profit (loss) before interest and tax adjusted for
     
(8,101)
(103)
(2,700)
 
  fair value accounting effects
 
(2,803)
(5,365)
(147)
(322)
(216)
 
Impact of fair value accounting effects
 
(538)
(249)
(8,248)
(425)
(2,916)
 
Profit (loss) before interest and tax
 
(3,341)
(5,614)


Top of page 29
Additional information (continued)
 

Realizations and marker prices

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
     
2016
2015
       
Average realizations(a)
     
       
Liquids* ($/bbl)
     
50.97
28.75
34.89
 
US
 
31.82
48.53
57.42
31.73
43.62
 
Europe
 
37.46
55.25
60.78
25.16
55.10
 
Rest of World
 
35.97
52.63
56.69
26.97
44.99
 
BP Average
 
34.63
51.49
       
Natural gas ($/mcf)
     
2.15
1.57
1.53
 
US
 
1.55
2.27
9.16
4.30
4.64
 
Europe
 
4.46
8.27
4.05
3.31
3.10
 
Rest of World
 
3.21
4.57
3.80
2.84
2.66
 
BP Average
 
2.75
4.12
       
Total hydrocarbons* ($/boe)
     
34.93
20.73
24.00
 
US
 
22.38
34.04
56.35
29.81
39.25
 
Europe
 
34.28
53.28
39.93
22.53
33.90
 
Rest of World
 
27.34
38.58
40.04
22.57
30.63
 
BP Average
 
26.24
38.47
       
Average oil marker prices ($/bbl)
     
61.88
33.94
45.59
 
Brent
 
39.81
57.84
57.85
33.45
45.53
 
West Texas Intermediate
 
39.64
53.25
49.56
22.11
33.78
 
Western Canadian Select
 
28.09
43.12
62.65
33.98
45.74
 
Alaska North Slope
 
40.00
57.39
59.57
30.14
42.08
 
Mars
 
36.25
54.44
61.21
31.66
43.37
 
Urals (NWE – cif)
 
37.56
56.83
       
Average natural gas marker prices
     
2.65
2.09
1.95
 
Henry Hub gas price ($/mmBtu)(b)
 
2.02
2.82
44.63
30.42
31.37
 
UK Gas – National Balancing Point (p/therm)
 
30.90
46.29

(a)
Based on sales of consolidated subsidiaries only – this excludes equity-accounted entities.
(b)
Henry Hub First of Month Index.


Exchange rates

Second
First
Second
     
First
First
quarter
quarter
quarter
     
half
half
2015
2016
2016
     
2016
2015
1.53
1.43
1.43
 
$/£ average rate for the period
 
1.43
1.52
1.57
1.44
1.34
 
$/£ period-end rate
 
1.34
1.57
               
1.11
1.10
1.13
 
$/€ average rate for the period
 
1.12
1.12
1.11
1.14
1.11
 
$/€ period-end rate
 
1.11
1.11
               
52.68
74.97
65.86
 
Rouble/$ average rate for the period
 
70.35
57.94
55.42
67.31
63.64
 
Rouble/$ period-end rate
 
63.64
55.42


Top of page 30
Glossary
 

Capital expenditure on an accruals basis is a non-GAAP measure. It comprises additions to property, plant and equipment, intangible assets and investments in joint ventures and associates, and reflects consideration payable in business combinations. It does not include additions arising from asset exchanges and certain other non-cash items.

Consolidation adjustment – UPII is unrealized profit in inventory arising on inter-segment transactions.

Fair value accounting effects are non-GAAP adjustments to our IFRS profit (loss) relating to certain physical inventories, pipelines and storage capacity. Management uses a fair-value basis to value these items which, under IFRS, are accounted for on an accruals basis with the exception of trading inventories, which are valued using spot prices. The adjustments have the effect of aligning the valuation basis of the physical positions with that of any associated derivative instruments, which are required to be fair valued under IFRS, in order to provide a more representative view of the ultimate economic value. Further information and a reconciliation to GAAP information is provided on page 28.

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

Inorganic capital expenditure is a non-GAAP measure. It comprises consideration in business combinations and certain other significant investments made by the group. Inorganic capital expenditure is reported on an accruals basis.

Inventory holding gains and losses represent the difference between the cost of sales calculated using the replacement cost of inventory and the cost of sales calculated on the first-in first-out (FIFO) method after adjusting for any changes in provisions where the net realizable value of the inventory is lower than its cost. Under the FIFO method, which we use for IFRS reporting, the cost of inventory charged to the income statement is based on its historical cost of purchase or manufacture, rather than its replacement cost. In volatile energy markets, this can have a significant distorting effect on reported income. The amounts disclosed represent the difference between the charge to the income statement for inventory on a FIFO basis (after adjusting for any related movements in net realizable value provisions) and the charge that would have arisen based on the replacement cost of inventory. For this purpose, the replacement cost of inventory is calculated using data from each operation’s production and manufacturing system, either on a monthly basis, or separately for each transaction where the system allows this approach. The amounts disclosed are not separately reflected in the financial statements as a gain or loss. No adjustment is made in respect of the cost of inventories held as part of a trading position and certain other temporary inventory positions. See Replacement cost (RC) profit or loss definition below.

Joint arrangement is an arrangement in which two or more parties have joint control.

LiquidsLiquids for Upstream and Rosneft comprises crude oil, condensate and natural gas liquids. For Upstream, liquids also includes bitumen.
 
Major projects have a BP net investment of at least $250 million, or are considered to be of strategic importance to BP or of a high degree of complexity.

Net debt and net debt ratio are non-GAAP measures. Net debt is calculated as gross finance debt, as shown in the balance sheet, plus the fair value of associated derivative financial instruments that are used to hedge foreign currency exchange and interest rate risks relating to finance debt, for which hedge accounting is applied, less cash and cash equivalents. The net debt ratio is defined as the ratio of net debt to the total of net debt plus shareholders’ equity. All components of equity are included in the denominator of the calculation. BP believes 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. The derivatives are reported on the balance sheet within the headings ‘Derivative financial instruments’.

Net wind generation 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 gross data is the equivalent capacity on a gross-JV basis, which includes 100% of the capacity of equity-accounted entities where BP has partial ownership.

Non-operating items are charges and credits included in the financial statements that BP discloses separately because it considers such disclosures to be meaningful and relevant to investors. They are items that management considers not to be part of underlying business operations and are disclosed in order to enable investors better to understand and evaluate the group’s reported financial performance. Non-operating items within equity-accounted earnings are reported net of incremental income tax reported by the equity-accounted entity. An analysis of non-operating items by region is shown on pages 5, 7 and 9, and by segment and type is shown on page 27.

Organic capital expenditure is a non-GAAP measure. It comprises capital expenditure on an accruals basis less inorganic capital expenditure. An analysis of organic capital expenditure by segment and region is shown on page 26.

Production-sharing agreement (PSA) is an arrangement through which an oil company bears the risks and costs of exploration, development and production. In return, if exploration is successful, the oil company receives entitlement to variable physical volumes of hydrocarbons, representing recovery of the costs incurred and a stipulated share of the production remaining after such cost recovery.


Top of page 31
Glossary (continued)
 

Realizations are the result of dividing revenue generated from hydrocarbon sales, excluding revenue generated from purchases made for resale and royalty volumes, by revenue generating hydrocarbon production volumes. Revenue generating hydrocarbon production reflects the BP share of production as adjusted for any production which does not generate revenue. Adjustments may include losses due to shrinkage, amounts consumed during processing, and contractual or regulatory host committed volumes such as royalties.

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 downtime.

The Refining marker margin (RMM) is the average of regional indicator margins weighted for BP’s crude refining capacity in each region. Each regional marker margin is based on product yields and a marker crude oil deemed appropriate for the region. The regional indicator margins may not be representative of the margins achieved by BP in any period because of BP’s particular refinery configurations and crude and product slate.

Replacement cost (RC) profit or loss reflects the replacement cost of inventories sold in the period and is arrived at by excluding inventory holding gains and losses from profit or loss. RC profit or loss is the measure of profit or loss that is required to be disclosed for each operating segment under International Financial Reporting Standards (IFRS). RC profit or loss for the group is not a recognized GAAP measure. Management believes this measure is useful to illustrate to investors the fact that crude oil and product prices can vary significantly from period to period and that the impact on our reported result under IFRS can be significant. Inventory holding gains and losses vary from period to period due to changes in prices as well as changes in underlying inventory levels. In order for investors to understand the operating performance of the group excluding the impact of price changes on the replacement of inventories, and to make comparisons of operating performance between reporting periods, BP’s management believes it is helpful to disclose this measure.

Underlying production is production after adjusting for divestments and entitlement impacts in our production-sharing agreements.

Underlying RC profit or loss is RC profit or loss after adjusting for non-operating items and fair value accounting effects. Underlying RC profit or loss and fair value accounting effects are not recognized GAAP measures. See pages 27 and 28 for additional information on the non-operating items and fair value accounting effects that are used to arrive at underlying RC profit or loss in order to enable a full understanding of the events and their financial impact.

BP believes that underlying RC profit or loss is a useful measure for investors because it is a measure closely tracked by management to evaluate BP’s operating performance and to make financial, strategic and operating decisions and because it may help investors to understand and evaluate, in the same manner as management, the underlying trends in BP’s operational performance on a comparable basis, period on period, by adjusting for the effects of these non-operating items and fair value accounting effects. The nearest equivalent measure on an IFRS basis for the group is profit or loss for the year attributable to BP shareholders. The nearest equivalent measure on an IFRS basis for segments is RC profit or loss before interest and taxation.


Top of page 32
 
Principal risks and uncertainties
 

The principal risks and uncertainties affecting BP are described in the Risk factors section of BP Annual Report and Form 20-F 2015 (pages 53-54) and are summarized below. Other than the removal of the Gulf of Mexico oil spill Risk factor (following the announcement on 14 July 2016 of the non-operating charge to be taken associated with the oil spill), there are no material changes in those risk factors for the remaining six months of the financial year.

The risks summarized below, separately or in combination, could have a material adverse effect on the implementation of our strategy, our business, financial performance, results of operations, cash flows, liquidity, prospects, shareholder value and returns and reputation.

Strategic and commercial risks
·  
Prices and markets – our financial performance is subject to fluctuating prices of oil, gas, refined products, technological change, exchange rate fluctuations, and the general macroeconomic outlook.
·  
Access, renewal and reserves progression – our inability to access, renew and progress upstream resources in a timely manner could adversely affect our long-term replacement of reserves.
·  
Major project* delivery – failure to invest in the best opportunities or deliver major projects successfully could adversely affect our financial performance.
·  
Geopolitical – we are exposed to a range of political developments and consequent changes to the operating and regulatory environment.
·  
Liquidity, financial capacity and financial, including credit, exposure – failure to work within our financial framework could impact our ability to operate and result in financial loss.
·  
Joint arrangements* and contractors – we may have limited control over the standards, operations and compliance of our partners, contractors and sub-contractors.
·  
Digital infrastructure and cybersecurity – breach of our digital security or failure of our digital infrastructure could damage our operations and our reputation.
·  
Climate change and carbon pricing – public policies could increase costs and reduce future revenue and strategic growth opportunities.
·  
Competition – inability to remain efficient, innovate and retain an appropriately skilled workforce could negatively impact delivery of our strategy in a highly competitive market.
·  
Crisis management and business continuity – potential disruption to our business and operations could occur if we do not address an incident effectively.
·  
Insurance – our insurance strategy could expose the group to material uninsured losses.

Safety and operational risks
·  
Process safety, personal safety, and environmental risks – we are exposed to a wide range of health, safety, security and environmental risks that could result in regulatory action, legal liability, increased costs, damage to our reputation and potentially denial of our licence to operate.
·  
Drilling and production – challenging operational environments and other uncertainties can impact drilling and production activities.
·  
Security – hostile acts against our staff and activities could cause harm to people and disrupt our operations.
·  
Product quality – supplying customers with off-specification products could damage our reputation, lead to regulatory action and legal liability, and potentially impact our financial performance.

Compliance and control risks
·  
US government settlements – failure to comply with the terms of our settlements with legal and regulatory bodies in the US announced in November 2012 in respect of certain charges related to the Gulf of Mexico oil spill may expose us to further penalties or liabilities or could result in suspension or debarment of certain BP entities.
·  
Regulation – changes in the regulatory and legislative environment could increase the cost of compliance, affect our provisions and limit our access to new exploration opportunities.
·  
Ethical misconduct and non-compliance – ethical misconduct or breaches of applicable laws by our businesses or our employees could be damaging to our reputation, and could result in litigation, regulatory action and penalties.
·  
Treasury and trading activities – ineffective oversight of treasury and trading activities could lead to business disruption, financial loss, regulatory intervention or damage to our reputation.
·  
Reporting – failure to accurately report our data could lead to regulatory action, legal liability and reputational damage.


Top of page 33
Legal proceedings
 

The following discussion sets out the material developments in the group’s material legal proceedings during the half year 2016. For a full discussion of the group’s material legal proceedings, see pages 237-242 of BP Annual Report and Form 20-F 2015.

Matters relating to the Deepwater Horizon accident and oil spill (the Incident)

Consent Decree and Settlement Agreement On 2 July 2015, BP reached agreements in principle with the United States federal government and five Gulf states to settle all federal and state claims arising from the Incident. On 5 October 2015, the United States lodged a proposed Consent Decree with the federal district court in New Orleans to resolve all United States and Gulf states natural resource damage claims and all Clean Water Act penalty claims and certain other claims. At the same time, BP entered a Settlement Agreement with the Gulf states for economic, property and other losses. On 22 March 2016, the United States filed a motion with the court to enter the Consent Decree as a final settlement. On 4 April 2016, the court entered the Consent Decree and also entered a final judgment on the terms set forth in the Consent Decree, at which time the Consent Decree and Settlement Agreement became effective.

Oil Pollution Act (OPA) Test Case Proceedings  Six OPA test cases were before the federal district court to address certain OPA liability questions focusing on, among other issues, whether plaintiffs’ alleged losses tied to the 2010 federal government moratoria on deepwater drilling and federal permit delays are compensable. In December 2015, BP filed a motion to dismiss plaintiffs’ claims arising from the moratoria or permit process, and plaintiffs filed a motion asking the court to prevent BP from arguing that government action and/or inaction following the oil spill is a “superseding” cause with respect to some or all of the damages that plaintiffs claim. On 10 March 2016, the court granted BP’s motion and denied the plaintiffs’ motion, ruling that BP is not, as a “Responsible Party” under OPA, liable for economic losses that resulted from the 2010 deepwater drilling moratoria. The court’s order dismissed the plaintiffs’ claims with prejudice. On 19 March 2016, the plaintiffs appealed the court’s ruling to the Fifth Circuit.

Securities Class Action  Since the Incident, shareholders have sued BP and various of its current and former officers and directors asserting class securities fraud claims. On 31 May 2016, the federal district court in Houston issued a decision on the parties’ summary judgment motions in relation to the claims by the class of post-explosion ADS purchasers from 26 April 2010 to 28 May 2010. In that decision, the court denied the plaintiffs’ motion and granted in part and denied in part BP’s motion. Following that decision, on 2 June 2016, BP announced that it agreed with the plaintiffs’ representatives to settle the post-explosion class claims for the amount of $175 million, payable during 2016-2017, subject to approval by the court. The parties are preparing the final settlement agreement and other papers in support of approval for submission to the court.

Other Civil Complaints  On 29 March 2016, the federal district court in New Orleans issued an order (the March Order) dismissing in its entirety the master complaint raising claims for economic loss and property damage by private plaintiffs relating to the Incident. The court ordered all private plaintiffs who filed a timely claim for economic loss or property damage and did not release those claims to file and serve on BP by 2 May 2016 a sworn statement disclosing information regarding their claims. In addition, the court required most plaintiffs who had not filed an individual complaint (defined as a complaint not joined in by other plaintiffs) against BP to file a new individual complaint by 2 May 2016. The court further ordered that plaintiffs who failed to comply with the order by 2 May 2016 (later extended by 14 days for many plaintiffs) would have their claims deemed dismissed with prejudice without further notice. On 7 June 2016, the court issued an order requiring private plaintiffs who had not complied with the March Order to show cause in writing by 28 June 2016 why their claims should not be dismissed with prejudice. The court also dismissed all joinders by plaintiffs in the master complaint for private plaintiff economic loss and property damages claims. On 14 July 2016 the federal district court issued an order listing those plaintiffs who complied with the March Order and those plaintiffs whose compliance with the March Order remains to be determined by the court. The court dismissed with prejudice any remaining claims by private plaintiffs for economic loss and property damage. Accordingly the vast majority of economic loss and property damage claims from individuals and businesses that either opted out of the 2012 settlement with the Plaintiffs’ Steering Committee and/or were excluded from that settlement have either been resolved or dismissed.

Non-US Government Lawsuits  On 18 October 2012, before a Mexican Federal District Court located in Mexico City, a class action complaint was filed against BP Exploration & Production Inc., BP America Production Company and other BP subsidiaries seeking, among other things, compensatory damages for the class members who allegedly suffered economic losses, as well as an order requiring BP to remediate environmental damage resulting from the Incident, to provide funding for the preservation of the environment and to conduct environmental impact studies in the Gulf of Mexico for the next 10 years. BP has not been formally served with the action. However, after learning that the Mexican Federal District Court issued a resolution in the class action that impacted BP’s rights, BP filed a constitutional challenge in Mexico asserting that BP has never been formally served with process in the class action. This challenge remains pending.

On 3 December 2015 and 29 March 2016, Acciones Colectivas de Sinaloa filed two class actions in the Mexican Federal District Court on behalf of several Mexican States.  In these class actions, plaintiffs seek an order requiring the BP defendants to repair the damage to the Gulf of Mexico, to pay penalties, and to compensate plaintiffs for damage to property, to health and for economic loss. BP has not been formally served with either class action.


Top of page 34
Legal proceedings (continued)
 

CSB Investigation  On 13 April 2016, the US Chemical Safety and Hazard Investigation Board (CSB) publicly released drafts of the final two volumes of its four-volume report on its investigation into the Incident. The final two volumes primarily concern the role of the regulator in the oversight of the offshore industry and organizational and cultural factors. They include proposed recommendations to the US Department of Interior’s Bureau of Safety and Environmental Enforcement, the American Petroleum Institute, the Ocean Energy Safety Institute and the Sustainability Accounting Standards Board.

Other legal proceedings

FERC and CFTC Matters  The US Federal Energy Regulatory Commission (FERC) and the US Commodity Futures Trading Commission (CFTC) investigated several BP entities regarding trading in the next-day natural gas market at Houston Ship Channel in 2008. The FERC Administrative Law Judge ruled on 13 August 2015 that BP manipulated the market by selling next-day, fixed price natural gas at Houston Ship Channel in 2008 in order to suppress the Gas Daily index and benefit its financial position. On 11 July 2016, the FERC issued an order affirming the initial decision and directing BP to pay a civil penalty of $20.2 million and to disgorge $0.2 million in unjust profits. BP intends to seek rehearing before the FERC and ultimately appeal to the US court of appeal if necessary.

CSB Matters  In March 2007, the CSB issued a report on the March 2005 explosion and fire at the Texas City refinery incident. The report contained recommendations to the BP Texas City refinery and to the board of directors of BP. On 25 May 2016, the CSB closed its last open recommendation to BP. The CSB has now accepted that all of BP’s responses to its recommendations have been satisfactorily addressed.

Scharfstein v. BP West Coast Products, LLC  A purported class action lawsuit was filed against BP West Coast Products, LLC in Oregon State Court under the Oregon Unlawful Trade Practices Act on behalf of customers who used a debit card at ARCO gasoline stations in Oregon during the period 1 January 2011 to 30 August 2013, alleging that ARCO’s Oregon sites failed to provide sufficient notice of the 35 cents per transaction debit card fee. After a jury trial and subsequent hearing, in 2014 the jury rendered a verdict against BP. On 31 May 2016, the court entered a judgment for the amount of $417.3 million. On 1 June 2016, BP filed a notice of appeal. No provision has been made for damages arising out of this class action.


Top of page 35
Cautionary statement
 

In order to utilize the ‘safe harbor’ provisions of the United States Private Securities Litigation Reform Act of 1995 (the ‘PSLRA’), BP is providing the following cautionary statement: The discussion in this results announcement contains certain forecasts, projections and forward-looking statements – that is, statements related to future, not past events – with respect to the financial condition, results of operations and businesses of BP and certain of the plans and objectives of BP with respect to these items. These statements may generally, but not always, be identified by the use of words such as ‘will’, ‘expects’, ‘is expected to’, ‘aims’, ‘should’, ‘may’, ‘objective’, ‘is likely to’, ‘intends’, ‘believes’, ‘anticipates’, ‘plans’, ‘we see’ or similar expressions. In particular, among other statements, the expected quarterly dividend payment and timing of such payment; plans and expectations regarding Upstream activities in Azerbaijan, the Gulf of Mexico, Norway, the Russian Federation, Egypt, Indonesia, Kuwait and China; expectations regarding the planned restructuring of the German refining joint operation with Rosneft and the combination of BP’s and Det norske’s Norwegian businesses; expectations regarding Upstream third-quarter 2016 reported production and Downstream third-quarter 2016 turnaround activity and industry refining margins; statements regarding the estimate of the amount of dividend payable by Rosneft to BP; expectations with respect to the total amounts that will ultimately be paid by BP in relation to the Gulf of Mexico incident and the timing thereof; and certain statements regarding the legal and trial proceedings, court decisions, claims, penalties, potential investigations and civil actions by regulators, government entities and/or other entities or parties and the risks associated with such proceedings; are all forward looking in nature. By their nature, forward-looking statements involve risk and uncertainty because they relate to events and depend on circumstances that will or may occur in the future and are outside the control of BP. Actual results may differ materially from those expressed in such statements, depending on a variety of factors, including: the specific factors identified in the discussions accompanying such forward-looking statements; the receipt of relevant third party and/or regulatory approvals; the timing and level of maintenance and/or turnaround activity; the timing and volume of refinery additions and outages; the timing of bringing new fields onstream; the timing, quantum and nature of certain divestments; future levels of industry product supply, demand and pricing, including supply growth in North America; OPEC quota restrictions; PSA effects; operational and safety problems; potential lapses in product quality; economic and financial market conditions generally or in various countries and regions; political stability and economic growth in relevant areas of the world; changes in laws and governmental regulations; regulatory or legal actions including the types of enforcement action pursued and the nature of remedies sought or imposed; the actions of prosecutors, regulatory authorities and courts; exchange rate fluctuations; development and use of new technology; recruitment and retention of a skilled workforce; the success or otherwise of partnering; the actions of competitors, trading partners, contractors, subcontractors, creditors, rating agencies and others; our access to future credit resources; business disruption and crisis management; the impact on our reputation of ethical misconduct and non-compliance with regulatory obligations; trading losses; major uninsured losses; decisions by Rosneft’s management and board of directors; the actions of contractors; natural disasters and adverse weather conditions; changes in public expectations and other changes to business conditions; wars and acts of terrorism; cyber-attacks or sabotage; and other factors discussed elsewhere in this report and under “Risk factors” in BP Annual Report and Form 20-F 2015 as filed with the US Securities and Exchange Commission.




Contacts
 

 
London
Houston
     
Press Office
David Nicholas
Brett Clanton
 
+44 (0)20 7496 4708
+1 281 366 8346
     
Investor Relations
Jessica Mitchell
Craig Marshall
bp.com/investors
+44 (0)20 7496 4962
+1 281 892 4312
 
 

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: 26 July 2016
 
/s/ J. BERTELSEN
...............................
J. BERTELSEN
Deputy Company Secretary