2Q16 Part 1 of 1

RNS Number : 1829F
BP PLC
26 July 2016
 

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


(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)


1,383





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


Profit (loss) before interest and tax


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


Of which: Exploration expenditure written off(a)






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




2,753

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

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) before interest 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-controllinginterests


(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)




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.

 

Liquids - Liquids 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.

 

 

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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

 

 

 

 


This information is provided by RNS
The company news service from the London Stock Exchange
 
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