UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 6-K
Report of Foreign Private Issuer
Pursuant to Rule 13a-16 or 15d-16 of
the Securities Exchange Act of 1934
for the period ended 31 March 2017
Commission File Number 1-06262
BP p.l.c.
(Translation of registrants name into English)
1 ST JAMESS SQUARE, LONDON, SW1Y 4PD, ENGLAND
(Address of principal executive offices)
Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F.
Form 20-F | ✓ | Form 40-F |
Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(1):
Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(7):
THIS REPORT ON FORM 6-K SHALL BE DEEMED TO BE INCORPORATED BY REFERENCE IN THE PROSPECTUS INCLUDED IN THE REGISTRATION STATEMENT ON FORM F-3 (FILE NOS. 333-208478 AND 333-208478-01) OF BP CAPITAL MARKETS p.l.c. AND BP p.l.c.; THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-67206) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-79399) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-103924) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-123482) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-123483) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-131583) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-131584) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-132619) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-146868) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-146870) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-146873) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-173136) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-177423) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-179406) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-186462) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-186463) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-199015) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-200794) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-200795) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-207188) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-207189) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-210316) OF BP p.l.c., THE REGISTRATION STATEMENT ON FORM S-8 (FILE NO. 333-210318) OF BP p.l.c., AND TO BE A PART THEREOF FROM THE DATE ON WHICH THIS REPORT IS FURNISHED, TO THE EXTENT NOT SUPERSEDED BY DOCUMENTS OR REPORTS SUBSEQUENTLY FILED OR FURNISHED.
1
Form 6-K for the period ended 31 March 2017(a)
|
Page | ||||||
1. | 3-13, 25-34 | |||||
2. | 14-24 | |||||
3. | 35 | |||||
4. | 35 | |||||
5. | 36 | |||||
6. | 37 | |||||
7. | 38 |
(a) | In this Form 6-K, references to the first quarter 2017 and first quarter 2016 refer to three-month periods ended 31 March 2017 and 31 March 2016 respectively. |
(b) | This discussion should be read in conjunction with the consolidated financial statements and related notes provided elsewhere in this Form 6-K and with the information, including the consolidated financial statements and related notes, in BPs Annual Report on Form 20-F for the year ended 31 December 2016. |
2
Group results first quarter 2017
London 2 May 2017
Highlights | Robust earnings and cash flow, new projects on track. | |||
·
·
·
·
·
·
· |
Profit for the first quarter was $1.4 billion, underlying replacement cost profit* for the first quarter was $1.5 billion.
First quarter operating cash flow* was $2.1 billion after post-tax Gulf of Mexico oil spill expenditure of $2.3 billion.
Dividend unchanged at 10 cents per share.
Reported oil and gas production was 3.5mmboe/d in the first quarter, 5% higher than same period in 2016.
New Upstream major projects* on track: Trinidad onshore compression project started up, another in ramp-up, and two more in commissioning.
Downstream marketing growth and strong operational performance.
$1.7 billion divestment of BPs interest in SECCO petrochemical joint venture, subject to regulatory approvals. |
|
||||||||||||
First | First | |||||||||||
quarter | quarter | |||||||||||
$ million | 2017 | 2016 | ||||||||||
Profit (loss) for the period(a) |
1,449 | (583) | ||||||||||
Inventory holding (gains) losses*, before tax |
(66) | 132 | ||||||||||
Taxation charge (credit) on inventory holding gains and losses |
29 | (34) | ||||||||||
Replacement cost profit (loss)* |
1,412 | (485) | ||||||||||
Net (favourable) unfavourable impact of non-operating items* and fair
value accounting effects*, |
267 | 1,410 | ||||||||||
Taxation charge (credit) on non-operating items and fair value accounting effects |
(169) | (393) | ||||||||||
Underlying replacement cost profit |
1,510 | 532 | ||||||||||
Profit (loss) per ordinary share (cents) |
7.42 | (3.16) | ||||||||||
Profit (loss) per ADS (dollars) |
0.45 | (0.19) | ||||||||||
Replacement cost profit (loss) per ordinary share (cents)* |
7.23 | (2.63) | ||||||||||
Replacement cost profit (loss) per ADS (dollars) |
0.43 | (0.16) | ||||||||||
Underlying replacement cost profit per ordinary share (cents)* |
7.74 | 2.88 | ||||||||||
Underlying replacement cost profit per ADS (dollars) |
0.46 | 0.17 |
(a) | Profit attributable to BP shareholders. |
BP focused on disciplined delivery. |
Bob Dudley - Group chief executive
Our year has started well. BP is focused on the disciplined delivery of our plans. First quarter earnings and cash flow were robust. We have shown continued operational momentum - it was another strong quarter for the Downstream and the first of our seven new Upstream major projects has started up, with a further three near completion. We expect these to drive a material improvement in operating cash flow from the second half. |
* For items marked with an asterisk throughout this document, definitions are provided in the Glossary on page 31.
The commentary above and following should be read in conjunction with the cautionary statement on page 35.
3
Group headlines
4
Analysis of underlying RC profit before interest and tax
$ million | First quarter 2017 |
First quarter 2016 | ||||
Underlying RC profit before interest and tax* |
||||||
Upstream |
1,370 | (747) | ||||
Downstream |
1,742 | 1,813 | ||||
Rosneft |
99 | 66 | ||||
Other businesses and corporate |
(440) | (178) | ||||
Consolidation adjustment UPII* |
(68) | 40 | ||||
Underlying RC profit before interest and tax |
2,703 | 994 | ||||
Finance costs and net finance expense relating to pensions and other post-retirement benefits |
(387) | (317) | ||||
Taxation on an underlying RC basis |
(763) | (120) | ||||
Non-controlling interests |
(43) | (25) | ||||
Underlying RC profit attributable to BP shareholders |
1,510 | 532 |
Reconciliations of underlying RC profit or loss to the nearest equivalent IFRS measure are provided on page 3 for the group and on pages 8-13 for the segments.
Analysis of RC profit (loss) before interest and tax and reconciliation to profit (loss) for the period
$ million | First quarter 2017 |
First quarter 2016 | ||||
RC profit (loss) before interest and tax* |
||||||
Upstream |
1,256 | (1,205) | ||||
Downstream |
1,706 | 1,880 | ||||
Rosneft |
99 | 66 | ||||
Other businesses and corporate(a) |
(431) | (1,074) | ||||
Consolidation adjustment UPII |
(68) | 40 | ||||
RC profit (loss) before interest and tax |
2,562 | (293) | ||||
Finance costs and net finance expense relating to pensions and other post-retirement benefits |
(513) | (440) | ||||
Taxation on a RC basis |
(594) | 273 | ||||
Non-controlling interests |
(43) | (25) | ||||
RC profit (loss) attributable to BP shareholders |
1,412 | (485) | ||||
Inventory holding gains (losses) |
66 | (132) | ||||
Taxation (charge) credit on inventory holding gains and losses |
(29) | 34 | ||||
Profit (loss) for the period attributable to BP shareholders |
1,449 | (583) |
(a) | Includes costs related to the Gulf of Mexico oil spill. See page 13 and also Note 2 from page 19 for further information on the accounting for the Gulf of Mexico oil spill. |
5
The commentary above contains forward-looking statements and should be read in conjunction with the cautionary statement on page 35.
6
INTENTIONALLY BLANK
7
Upstream
$ million | First quarter |
First quarter | ||||
Profit (loss) before interest and tax |
1,250 | (1,236) | ||||
Inventory holding (gains) losses* |
6 | 31 | ||||
RC profit (loss) before interest and tax |
1,256 | (1,205) | ||||
Net (favourable) unfavourable impact of non-operating items* and fair value accounting effects* |
114 | 458 | ||||
Underlying RC profit before interest and tax*(a) |
1,370 | (747) |
(a) | See page 9 for a reconciliation to segment RC profit before interest and tax by region. |
Financial results
The replacement cost profit before interest and tax for the first quarter was $1,256 million, compared with a loss of $1,205 million for the same period in 2016. The first quarter included a net non-operating charge of $360 million, compared with a net non-operating charge of $355 million for the same period in 2016. Fair value accounting effects in the first quarter had a favourable impact of $246 million, compared with an unfavourable impact of $103 million in the same period of 2016.
After adjusting for non-operating items and fair value accounting effects, the underlying replacement cost profit before interest and tax for the first quarter was $1,370 million, compared with a loss of $747 million for the same period in 2016. The result for the first quarter mainly reflected higher liquids and gas realizations and higher production including the impact of the Abu Dhabi ADCO concession renewal, partly offset by higher depreciation, depletion and amortization and higher exploration write-offs.
Production
Production for the quarter was 2,388mboe/d, 3.0% higher than the first quarter of 2016. Underlying production* for the quarter increased by 3.0%, due to the ramp-up of major projects.
Key events
On 22 February, BPs previously announced transaction with Kosmos Energy in Senegal was approved by the Senegal Minister of Energy and of Development of Renewable Energies.
On 23 February, BP completed the purchase of a 10% interest from Eni (operator, 90%) in the Shorouk concession offshore Egypt, which contains the Zohr gas field.
On 27 March, BP announced its third gas discovery in the North Damietta Offshore Concession (BP 100%) in the East Nile Delta, Egypt.
On 3 April, BP announced that it had agreed to sell its Forties Pipeline System (FPS) business, with assets including the main Forties offshore and onshore pipelines and other associated pipeline interests and facilities, to INEOS. BPs existing rights to capacity in FPS will not be affected.
On 13 April, BP Trinidad and Tobago announced the start-up of the Trinidad onshore compression project.
Outlook
We expect second-quarter 2017 reported production to be broadly flat with the first quarter with the continued ramp-up of major projects* offset by seasonal turnaround and maintenance activities.
The commentary above contains forward-looking statements and should be read in conjunction with the cautionary statement on page 35.
8
Upstream (continued)
$ million | First quarter |
First quarter | ||||
Underlying RC profit (loss) before interest and tax |
||||||
US |
166 | (667) | ||||
Non-US |
1,204 | (80) | ||||
1,370 | (747) | |||||
Non-operating items |
||||||
US |
(12) | (163) | ||||
Non-US(a)(b) |
(348) | (192) | ||||
(360) | (355) | |||||
Fair value accounting effects |
||||||
US |
192 | (33) | ||||
Non-US |
54 | (70) | ||||
246 | (103) | |||||
RC profit (loss) before interest and tax |
||||||
US |
346 | (863) | ||||
Non-US |
910 | (342) | ||||
1,256 | (1,205) | |||||
Exploration expense |
||||||
US |
40 | 112 | ||||
Non-US(b)(c) |
372 | 142 | ||||
412 | 254 | |||||
Of which: Exploration expenditure written off(b)(c) |
261 | 161 | ||||
Production (net of royalties)(d) |
||||||
Liquids*(e) (mb/d) |
||||||
US |
448 | 403 | ||||
Europe |
115 | 128 | ||||
Rest of World(e) |
827 | 768 | ||||
1,389 | 1,299 | |||||
Of which equity-accounted entities |
213 | 171 | ||||
Natural gas (mmcf/d) |
||||||
US |
1,594 | 1,603 | ||||
Europe |
263 | 289 | ||||
Rest of World |
3,934 | 4,019 | ||||
5,791 | 5,910 | |||||
Of which equity-accounted entities |
530 | 467 | ||||
Total hydrocarbons*(e) (mboe/d) |
||||||
US |
723 | 679 | ||||
Europe |
160 | 178 | ||||
Rest of World(e) |
1,505 | 1,461 | ||||
2,388 | 2,318 | |||||
Of which equity-accounted entities |
305 | 251 | ||||
Average realizations*(f) |
||||||
Total liquids(e)(g) ($/bbl) |
49.87 | 29.61 | ||||
Natural gas ($/mcf) |
3.50 | 2.84 | ||||
Total hydrocarbons(e) ($/boe) |
37.19 | 23.81 |
(a) | First quarter 2017 relates primarily to an impairment charge arising following the announcement on 3 April 2017 of the agreement to sell the Forties Pipeline System business to INEOS. An impairment reversal of $30 million was also recorded in the quarter in relation to Block KG D6 in India. |
(b) | First quarter 2017 includes a $56-million write-back relating to Block KG D6 in India. This has been classified in the other category of non-operating items. |
(c) | First quarter 2017 includes a $297-million write-off of exploration wells in Egypt. |
(d) | Includes BPs share of production of equity-accounted entities in the Upstream segment. |
(e) | A minor adjustment has been made to first quarter 2016. See page 30 for more information. |
(f) | Realizations are based on sales by consolidated subsidiaries only this excludes equity-accounted entities. |
(g) | Includes condensate, natural gas liquids and bitumen. |
Because of rounding, some totals may not agree exactly with the sum of their component parts.
9
Downstream
$ million | First quarter 2017 |
First quarter 2016 |
||||||||
Profit (loss) before interest and tax |
1,804 | 1,783 | ||||||||
Inventory holding (gains) losses* |
(98) | 97 | ||||||||
RC profit before interest and tax |
1,706 | 1,880 | ||||||||
Net (favourable) unfavourable impact of non-operating items* and fair value accounting effects* |
36 | (67) | ||||||||
Underlying RC profit before interest and tax*(a) |
1,742 | 1,813 |
(a) | See page 11 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 first quarter was $1,706 million, compared with $1,880 million for the same period in 2016.
The first quarter includes a net non-operating charge of $76 million, compared with a net non-operating gain of $286 million for the same period in 2016. Fair value accounting effects had a favourable impact of $40 million in the first quarter, compared with an unfavourable impact of $219 million for the same period in 2016.
After adjusting for non-operating items and fair value accounting effects, the underlying replacement cost profit before interest and tax for the first quarter was $1,742 million, compared with $1,813 million for the same period in 2016.
Replacement cost profit before interest and tax for the fuels, lubricants and petrochemicals businesses is set out on page 11.
Fuels business
The fuels business reported an underlying replacement cost profit before interest and tax of $1,200 million for the first quarter, compared with $1,316 million for the same period in 2016. The result for the quarter reflects improved refining margins and a higher fuels marketing performance. This was more than offset by a higher level of turnaround activity and, whilst the supply and trading performance was strong, it reflected a lower contribution compared to the same period last year.
Lubricants business
The lubricants business reported an underlying replacement cost profit before interest and tax of $393 million for the first quarter, compared with $384 million for the same period in 2016.
Petrochemicals business
The petrochemicals business reported an underlying replacement cost profit before interest and tax of $149 million for the first quarter, compared with $113 million for the same period in 2016.
Following a review of our petrochemicals portfolio to focus on areas where we have leading proprietary technologies and competitive advantage, on 27 April 2017 we announced our intention to divest our 50% shareholding in our Shanghai SECCO Petrochemical Company Limited joint venture in China for a consideration of $1.7 billion. This transaction is subject to regulatory approvals.
Outlook
In the second quarter, we expect improved industry refining margins to be offset by both narrower North American heavy crude oil differentials and a higher level of turnaround activity compared with the first quarter.
The commentary above contains forward-looking statements and should be read in conjunction with the cautionary statement on page 35.
10
Downstream (continued)
$ million | First quarter 2017 |
First quarter 2016 |
||||||||
Underlying RC profit before interest and tax - by region |
||||||||||
US |
554 | 540 | ||||||||
Non-US |
1,188 | 1,273 | ||||||||
1,742 | 1,813 | |||||||||
Non-operating items |
||||||||||
US |
(12) | 113 | ||||||||
Non-US |
(64) | 173 | ||||||||
(76 | ) | 286 | ||||||||
Fair value accounting effects |
||||||||||
US |
(62) | (87) | ||||||||
Non-US |
102 | (132) | ||||||||
40 | (219) | |||||||||
RC profit before interest and tax |
||||||||||
US |
480 | 566 | ||||||||
Non-US |
1,226 | 1,314 | ||||||||
1,706 | 1,880 | |||||||||
Underlying RC profit before interest and tax - by business(a)(b) |
||||||||||
Fuels |
1,200 | 1,316 | ||||||||
Lubricants |
393 | 384 | ||||||||
Petrochemicals |
149 | 113 | ||||||||
1,742 | 1,813 | |||||||||
Non-operating items and fair value accounting effects(c) |
||||||||||
Fuels |
4 | 55 | ||||||||
Lubricants |
(3) | (1) | ||||||||
Petrochemicals |
(37) | 13 | ||||||||
(36) | 67 | |||||||||
RC profit (loss) before interest and tax(a)(b) |
||||||||||
Fuels |
1,204 | 1,371 | ||||||||
Lubricants |
390 | 383 | ||||||||
Petrochemicals |
112 | 126 | ||||||||
1,706 | 1,880 | |||||||||
BP average refining marker margin (RMM)* ($/bbl) |
11.7 | 10.5 | ||||||||
Refinery throughputs (mb/d) |
||||||||||
US |
694 | 699 | ||||||||
Europe |
801 | 807 | ||||||||
Rest of World |
181 | 238 | ||||||||
1,676 | 1,744 | |||||||||
Refining availability* (%) |
95.2 | 95.0 | ||||||||
Marketing sales of refined products (mb/d) |
||||||||||
US |
1,116 | 1,071 | ||||||||
Europe |
1,069 | 1,144 | ||||||||
Rest of World |
512 | 488 | ||||||||
2,697 | 2,703 | |||||||||
Trading/supply sales of refined products |
2,959 | 2,810 | ||||||||
Total sales volumes of refined products |
5,656 | 5,513 | ||||||||
Petrochemicals production (kte) |
||||||||||
US |
498 | 896 | ||||||||
Europe |
1,253 | 992 | ||||||||
Rest of World |
2,073 | 1,909 | ||||||||
3,824 | 3,797 |
(a) | Segment-level overhead expenses are included in the fuels business result. |
(b) | BPs 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. |
11
Rosneft
$ million | First quarter 2017(a) |
First quarter 2016 |
||||||||
Profit before interest and tax(b) |
73 | 62 | ||||||||
Inventory holding (gains) losses* |
26 | 4 | ||||||||
RC profit before interest and tax |
99 | 66 | ||||||||
Net charge (credit) for non-operating items* |
- | - | ||||||||
Underlying RC profit before interest and tax* |
99 | 66 |
Financial results
Replacement cost profit before interest and tax and underlying replacement cost profit before interest and tax for the first quarter was $99 million, compared with $66 million for the same period in 2016. There were no non-operating items in the first quarter of either year.
Compared with the same period in 2016, the result for the first quarter was primarily affected by adverse foreign exchange effects and higher oil prices.
On 24 April 2017, Rosneft announced that the board of directors had given their preliminary approval of the companys 2016 annual report and recommended that the annual general meeting (AGM) adopts a resolution to pay dividends of 5.98 roubles per one ordinary share which constitutes 35% of the companys IFRS net profit. BP expects to receive a dividend in relation to the 2016 annual results of 11.3 billion roubles, after the deduction of withholding tax, subject to approval at the AGM.
Key events
In April Rosneft completed the acquisition of a 100% interest in the Kondaneft project that is developing four licence areas in the Khanty-Mansiysk Autonomous District in West Siberia. The acquisition price is expected to be approximately $700 million.
First quarter 2017(a) |
First quarter 2016 |
|||||||||
Production (net of royalties) (BP share) |
||||||||||
Liquids* (mb/d) |
912 | 808 | ||||||||
Natural gas (mmcf/d) |
1,334 | 1,282 | ||||||||
Total hydrocarbons* (mboe/d) |
1,142 | 1,029 |
(a) | The operational and financial information of the Rosneft segment for the first quarter is based on preliminary operational and financial results of Rosneft for the three months ended 31 March 2017. Actual results may differ from these amounts. |
(b) | The Rosneft segment result includes equity-accounted earnings arising from BPs 19.75% shareholding in Rosneft as adjusted for the accounting required under IFRS relating to BPs purchase of its interest in Rosneft and the amortization of the deferred gain relating to the divestment of BPs interest in TNK-BP. These adjustments have increased the reported profit before interest and tax for the first quarter in 2017, 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. BPs share of Rosnefts 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. BPs share of Rosnefts 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. |
12
Other businesses and corporate
$ million | First quarter 2017 |
First quarter 2016 |
||||||||
Profit (loss) before interest and tax |
||||||||||
Gulf of Mexico oil spill |
(35) | (794) | ||||||||
Other |
(396) | (280) | ||||||||
Profit (loss) before interest and tax |
(431) | (1,074) | ||||||||
Inventory holding (gains) losses* |
- | - | ||||||||
RC profit (loss) before interest and tax |
(431) | (1,074) | ||||||||
Net charge (credit) for non-operating items* |
||||||||||
Gulf of Mexico oil spill |
35 | 794 | ||||||||
Other |
(44) | 102 | ||||||||
Net charge (credit) for non-operating items |
(9) | 896 | ||||||||
Underlying RC profit (loss) before interest and tax* |
(440) | (178) | ||||||||
Underlying RC profit (loss) before interest and tax |
||||||||||
US |
(197) | (110) | ||||||||
Non-US |
(243) | (68) | ||||||||
(440) | (178) | |||||||||
Non-operating items |
||||||||||
US |
(38) | (848) | ||||||||
Non-US |
47 | (48) | ||||||||
9 | (896) | |||||||||
RC profit (loss) before interest and tax |
||||||||||
US |
(235) | (958) | ||||||||
Non-US |
(196) | (116) | ||||||||
(431) | (1,074) |
Other businesses and corporate comprises our alternative energy business, shipping, treasury, 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 first quarter was $431 million, compared with $1,074 million for the same period in 2016.
The first-quarter result included a net non-operating gain of $9 million, compared with a net non-operating charge of $896 million for the same period in 2016.
After adjusting for non-operating items, the underlying replacement cost loss before interest and tax for the first quarter was $440 million, compared with $178 million for the same period in 2016. The underlying charge in the first quarter was impacted by adverse foreign exchange effects, which had a favourable effect in the first quarter of 2016.
Alternative energy wind
Net wind generation capacity*(a) was 1,454MW at 31 March 2017 compared with 1,578MW at 31 March 2016. BPs net share of wind generation for the first quarter was 1,159GWh, compared with 1,347GWh for the same period in 2016.
(a) | Capacity figures include 23MW in the Netherlands managed by our Downstream segment at 31 March 2017 (23MW at 31 March 2016). |
13
Group income statement
$ million | First quarter 2017 |
First quarter 2016 |
||||||||
Sales and other operating revenues (Note 4) |
55,863 | 38,512 | ||||||||
Earnings from joint ventures - after interest and tax |
205 | 29 | ||||||||
Earnings from associates - after interest and tax |
151 | 142 | ||||||||
Interest and other income |
122 | 145 | ||||||||
Gains on sale of businesses and fixed assets |
45 | 338 | ||||||||
Total revenues and other income |
56,386 | 39,166 | ||||||||
Purchases |
41,137 | 26,603 | ||||||||
Production and manufacturing expenses(a) |
5,255 | 6,519 | ||||||||
Production and similar taxes (Note 5) |
306 | 14 | ||||||||
Depreciation, depletion and amortization |
3,842 | 3,730 | ||||||||
Impairment and losses on sale of businesses and fixed assets |
453 | 13 | ||||||||
Exploration expense |
412 | 254 | ||||||||
Distribution and administration expenses |
2,353 | 2,458 | ||||||||
Profit (loss) before interest and taxation |
2,628 | (425) | ||||||||
Finance costs(a) |
460 | 394 | ||||||||
Net finance expense relating to pensions and other post-retirement benefits |
53 | 46 | ||||||||
Profit (loss) before taxation |
2,115 | (865) | ||||||||
Taxation(a) |
623 | (307) | ||||||||
Profit (loss) for the period |
1,492 | (558) | ||||||||
Attributable to |
||||||||||
BP shareholders |
1,449 | (583) | ||||||||
Non-controlling interests |
43 | 25 | ||||||||
1,492 | (558) | |||||||||
Earnings per share (Note 6) |
||||||||||
Profit (loss) for the period attributable to BP shareholders |
||||||||||
Per ordinary share (cents) |
||||||||||
Basic |
7.42 | (3.16) | ||||||||
Diluted |
7.38 | (3.16) | ||||||||
Per ADS (dollars) |
||||||||||
Basic |
0.45 | (0.19) | ||||||||
Diluted |
0.44 | (0.19) |
(a) | See Note 2 for information on the impact of the Gulf of Mexico oil spill on these income statement line items. |
14
Group statement of comprehensive income
$ million | First quarter 2017 |
First quarter 2016 |
||||||||
Profit (loss) for the period |
1,492 | (558) | ||||||||
Other comprehensive income |
||||||||||
Items that may be reclassified subsequently to profit or loss |
||||||||||
Currency translation differences |
1,214 | 874 | ||||||||
Exchange gains (losses) on translation of foreign operations reclassified to gain or loss on sale of businesses and fixed assets |
1 | 6 | ||||||||
Available-for-sale investments |
2 | - | ||||||||
Cash flow hedges marked to market |
48 | (62) | ||||||||
Cash flow hedges reclassified to the income statement |
42 | 23 | ||||||||
Cash flow hedges reclassified to the balance sheet |
39 | 13 | ||||||||
Share of items relating to equity-accounted entities, net of tax |
231 | 290 | ||||||||
Income tax relating to items that may be reclassified |
(125) | (86) | ||||||||
1,452 | 1,058 | |||||||||
Items that will not be reclassified to profit or loss |
||||||||||
Remeasurements of the net pension and other post-retirement benefit liability or asset |
727 | (1,222) | ||||||||
Income tax relating to items that will not be reclassified |
(246) | 402 | ||||||||
481 | (820) | |||||||||
Other comprehensive income |
1,933 | 238 | ||||||||
Total comprehensive income |
3,425 | (320) | ||||||||
Attributable to |
||||||||||
BP shareholders |
3,363 | (351) | ||||||||
Non-controlling interests |
62 | 31 | ||||||||
3,425 | (320) |
15
Group statement of changes in equity
$ million | BP shareholders equity |
Non-controlling interests |
Total equity |
|||||||||||
At 1 January 2017 |
95,286 | 1,557 | 96,843 | |||||||||||
Total comprehensive income |
3,363 | 62 | 3,425 | |||||||||||
Dividends |
(1,304) | (15) | (1,319) | |||||||||||
Share-based payments, net of tax |
177 | - | 177 | |||||||||||
Share of equity-accounted entities changes in equity, net of tax |
118 | - | 118 | |||||||||||
Transactions involving non-controlling interests |
- | 38 | 38 | |||||||||||
At 31 March 2017 |
97,640 | 1,642 | 99,282 | |||||||||||
$ million | BP shareholders equity |
Non-controlling interests |
Total equity |
|||||||||||
At 1 January 2016 |
97,216 | 1,171 | 98,387 | |||||||||||
Total comprehensive income |
(351) | 31 | (320) | |||||||||||
Dividends |
(1,099) | (9) | (1,108) | |||||||||||
Share-based payments, net of tax |
265 | - | 265 | |||||||||||
Transactions involving non-controlling interests |
(1) | 66 | 65 | |||||||||||
At 31 March 2016 |
96,030 | 1,259 | 97,289 |
16
Group balance sheet
$ million |
31 March 2017 |
31 December 2016 |
||||||||
Non-current assets |
||||||||||
Property, plant and equipment |
129,817 | 129,757 | ||||||||
Goodwill |
11,256 | 11,194 | ||||||||
Intangible assets |
18,366 | 18,183 | ||||||||
Investments in joint ventures |
8,765 | 8,609 | ||||||||
Investments in associates |
15,484 | 14,092 | ||||||||
Other investments |
1,011 | 1,033 | ||||||||
Fixed assets |
184,699 | 182,868 | ||||||||
Loans |
550 | 532 | ||||||||
Trade and other receivables |
1,448 | 1,474 | ||||||||
Derivative financial instruments |
4,189 | 4,359 | ||||||||
Prepayments |
1,022 | 945 | ||||||||
Deferred tax assets |
4,883 | 4,741 | ||||||||
Defined benefit pension plan surpluses |
1,162 | 584 | ||||||||
197,953 | 195,503 | |||||||||
Current assets |
||||||||||
Loans |
259 | 259 | ||||||||
Inventories |
17,236 | 17,655 | ||||||||
Trade and other receivables |
21,004 | 20,675 | ||||||||
Derivative financial instruments |
2,467 | 3,016 | ||||||||
Prepayments |
1,092 | 1,486 | ||||||||
Current tax receivable |
1,115 | 1,194 | ||||||||
Other investments |
39 | 44 | ||||||||
Cash and cash equivalents |
23,794 | 23,484 | ||||||||
67,006 | 67,813 | |||||||||
Total assets |
264,959 | 263,316 | ||||||||
Current liabilities |
||||||||||
Trade and other payables |
37,548 | 37,915 | ||||||||
Derivative financial instruments |
2,330 | 2,991 | ||||||||
Accruals |
4,096 | 5,136 | ||||||||
Finance debt |
7,360 | 6,634 | ||||||||
Current tax payable |
1,821 | 1,666 | ||||||||
Provisions |
2,971 | 4,012 | ||||||||
56,126 | 58,354 | |||||||||
Non-current liabilities |
||||||||||
Other payables |
13,067 | 13,946 | ||||||||
Derivative financial instruments |
5,187 | 5,513 | ||||||||
Accruals |
451 | 469 | ||||||||
Finance debt |
54,472 | 51,666 | ||||||||
Deferred tax liabilities |
7,295 | 7,238 | ||||||||
Provisions |
20,272 | 20,412 | ||||||||
Defined benefit pension plan and other post-retirement benefit plan deficits |
8,807 | 8,875 | ||||||||
109,551 | 108,119 | |||||||||
Total liabilities |
165,677 | 166,473 | ||||||||
Net assets |
99,282 | 96,843 | ||||||||
Equity |
||||||||||
BP shareholders equity |
97,640 | 95,286 | ||||||||
Non-controlling interests |
1,642 | 1,557 | ||||||||
Total equity |
99,282 | 96,843 |
17
Condensed group cash flow statement
$ million | First quarter 2017 |
First quarter 2016 |
||||||||||
Operating activities |
||||||||||||
Profit (loss) before taxation |
2,115 | (865) | ||||||||||
Adjustments to reconcile profit (loss) before taxation to net cash provided by operating activities |
||||||||||||
Depreciation, depletion and amortization and exploration expenditure written off |
4,103 | 3,891 | ||||||||||
Impairment and (gain) loss on sale of businesses and fixed assets |
408 | (325) | ||||||||||
Earnings from equity-accounted entities, less dividends received |
(220) | (24) | ||||||||||
Net charge for interest and other finance expense, less net interest paid |
252 | 168 | ||||||||||
Share-based payments |
162 | 259 | ||||||||||
Net operating charge for pensions and other post-retirement benefits, less contributions and benefit payments for unfunded plans |
(73) | 32 | ||||||||||
Net charge for provisions, less payments |
(177) | 735 | ||||||||||
Movements in inventories and other current and non-current assets and liabilities |
(3,600) | (1,727) | ||||||||||
Income taxes paid |
(856) | (272) | ||||||||||
Net cash provided by operating activities |
2,114 | 1,872 | ||||||||||
Investing activities |
||||||||||||
Expenditure on property, plant and equipment, intangible and other assets |
(3,823) | (4,381) | ||||||||||
Acquisitions, net of cash acquired |
(42) | - | ||||||||||
Investment in joint ventures |
(20) | (4) | ||||||||||
Investment in associates |
(183) | (93) | ||||||||||
Total cash capital expenditure |
(4,068) | (4,478) | ||||||||||
Proceeds from disposal of fixed assets |
188 | 238 | ||||||||||
Proceeds from disposal of businesses, net of cash disposed |
73 | 911 | ||||||||||
Proceeds from loan repayments |
14 | 46 | ||||||||||
Net cash used in investing activities |
(3,793) | (3,283) | ||||||||||
Financing activities |
||||||||||||
Proceeds from long-term financing |
3,713 | 2,738 | ||||||||||
Repayments of long-term financing |
(917) | (3,559) | ||||||||||
Net increase (decrease) in short-term debt |
315 | (112) | ||||||||||
Net increase (decrease) in non-controlling interests |
30 | 70 | ||||||||||
Dividends paid |
- BP shareholders | (1,304) | (1,099) | |||||||||
- non-controlling interests | (15) | (9) | ||||||||||
Net cash provided by (used in) financing activities |
1,822 | (1,971) | ||||||||||
Currency translation differences relating to cash and cash equivalents |
167 | 42 | ||||||||||
Increase (decrease) in cash and cash equivalents |
310 | (3,340) | ||||||||||
Cash and cash equivalents at beginning of period |
23,484 | 26,389 | ||||||||||
Cash and cash equivalents at end of period |
23,794 | 23,049 |
18
Notes
Note 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 2016 included in BP Annual Report and Form 20-F 2016.
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 groups 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 2017, which do not differ significantly from those used in BP Annual Report and Form 20-F 2016.
Note 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 2016 - Financial statements - Note 2 and Legal proceedings from page 261.
The group income statement includes a pre-tax charge of $161 million for the first quarter in relation to the Gulf of Mexico oil spill. The cumulative pre-tax income statement charge since the incident, in April 2010, amounts to $62,746 million. The charge for the first quarter predominantly reflects finance costs relating to the unwinding of discounting effects.
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.
$ million | First quarter 2017 |
First quarter 2016 |
||||||||||
Income statement |
||||||||||||
Production and manufacturing expenses |
35 | 794 | ||||||||||
Profit (loss) before interest and taxation |
(35) | (794) | ||||||||||
Finance costs |
126 | 123 | ||||||||||
Profit (loss) before taxation |
(161) | (917) | ||||||||||
Taxation |
48 | 251 | ||||||||||
Profit (loss) for the period |
(113) | (666) |
19
Note 2. Gulf of Mexico oil spill (continued)
$ million | 31 March 2017 |
31 December 2016 |
||||||||||
Balance sheet |
||||||||||||
Current assets |
||||||||||||
Trade and other receivables |
264 | 194 | ||||||||||
Current liabilities |
||||||||||||
Trade and other payables |
(2,945) | (3,056) | ||||||||||
Provisions |
(1,296) | (2,330) | ||||||||||
Net current assets (liabilities) |
(3,977) | (5,192) | ||||||||||
Non-current assets |
||||||||||||
Deferred tax assets |
2,915 | 2,973 | ||||||||||
Non-current liabilities |
||||||||||||
Other payables |
(12,663) | (13,522) | ||||||||||
Provisions |
(54) | (112) | ||||||||||
Deferred tax liabilities |
5,226 | 5,119 | ||||||||||
Net non-current assets (liabilities) |
(4,576) | (5,542) | ||||||||||
Net assets (liabilities) |
(8,553) | (10,734) |
$ million | First quarter 2017 |
First quarter 2016 |
||||||||||
Cash flow statement - Operating activities |
||||||||||||
Profit (loss) before taxation |
(161) | (917) | ||||||||||
Adjustments to reconcile profit (loss) before taxation to net cash provided by operating activities |
||||||||||||
Net charge for interest and other finance expense, less net interest paid |
126 | 123 | ||||||||||
Net charge for provisions, less payments |
(5) | 757 | ||||||||||
Movements in inventories and other current and non-current assets and liabilities |
(2,254) | (1,088) | ||||||||||
Pre-tax cash flows |
(2,294) | (1,125) |
Net cash from operating activities relating to the Gulf of Mexico oil spill, on a post-tax basis, amounted to an outflow of $2,294 million in the first quarter including a $740 million Department of Justice plea agreement payment. For the same period in 2016, the amount was an outflow of $1,125 million.
(b) Provisions and other payables
Provisions
Movements in the remaining provisions, all of which relate to litigation and claims, are presented in the table below.
$ million | ||||||||
At 1 January 2017 |
2,442 | |||||||
Net increase in provision |
25 | |||||||
Reclassified to other payables |
(596) | |||||||
Utilization |
(521) | |||||||
At 31 March 2017 |
1,350 |
The 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.
20
Note 2. Gulf of Mexico oil spill (continued)
PSC settlement
The provision for the cost associated with the 2012 Plaintiffs Steering Committee (PSC) settlement has been determined based upon an expected value of the remaining claims, including business economic loss claims. Amounts to resolve remaining claims are expected to be substantially paid in 2017. However, the amounts ultimately payable may differ from the amount provided and the timing of payment is uncertain. A significant number of claims determined by the court-supervised settlement programme have been and may be appealed by BP and/or the claimants. Depending upon the resolution of these claims, the amount payable may differ from what is currently provided for.
Other payables
Other payables include amounts payable under the 2016 agreements with the United States and five Gulf coast states for natural resource damages, state claims and Clean Water Act penalties, amounts payable under the 2012 agreement with the US government to resolve all federal criminal claims arising from the incident, BPs remaining commitment to fund the Gulf of Mexico Research Initiative, and amounts payable for certain economic loss and property damage claims.
Further information on provisions, other payables, and contingent liabilities is provided in BP Annual Report and Form 20-F 2016 - Financial statements - Note 2.
Note 3. Analysis of replacement cost profit (loss) before interest and tax and reconciliation to profit (loss) before taxation
First | First | |||||||||||
quarter | quarter | |||||||||||
$ million | 2017 | 2016 | ||||||||||
Upstream |
1,256 | (1,205) | ||||||||||
Downstream |
1,706 | 1,880 | ||||||||||
Rosneft |
99 | 66 | ||||||||||
Other businesses and corporate(a) |
(431) | (1,074) | ||||||||||
2,630 | (333) | |||||||||||
Consolidation adjustment - UPII* |
(68) | 40 | ||||||||||
RC profit (loss) before interest and tax |
2,562 | (293) | ||||||||||
Inventory holding gains (losses)* |
||||||||||||
Upstream |
(6) | (31) | ||||||||||
Downstream |
98 | (97) | ||||||||||
Rosneft (net of tax) |
(26) | (4) | ||||||||||
Profit (loss) before interest and tax |
2,628 | (425) | ||||||||||
Finance costs |
460 | 394 | ||||||||||
Net finance expense relating to pensions and other post-retirement benefits |
53 | 46 | ||||||||||
Profit (loss) before taxation |
2,115 | (865) | ||||||||||
RC profit (loss) before interest and tax* |
||||||||||||
US |
513 | (1,256) | ||||||||||
Non-US |
2,049 | 963 | ||||||||||
2,562 | (293) |
(a) | Includes costs related to the Gulf of Mexico oil spill. See Note 2 for further information. |
21
Note 4. Segmental analysis
Sales and other operating revenues | First | First | ||||||||
quarter | quarter | |||||||||
$ million | 2017 | 2016 | ||||||||
By segment |
||||||||||
Upstream |
11,327 | 7,431 | ||||||||
Downstream |
50,080 | 34,552 | ||||||||
Other businesses and corporate |
285 | 396 | ||||||||
61,692 | 42,379 | |||||||||
Less: sales and other operating revenues between segments |
||||||||||
Upstream |
5,777 | 3,633 | ||||||||
Downstream |
(86) | 118 | ||||||||
Other businesses and corporate |
138 | 116 | ||||||||
5,829 | 3,867 | |||||||||
Third party sales and other operating revenues |
||||||||||
Upstream |
5,550 | 3,798 | ||||||||
Downstream |
50,166 | 34,434 | ||||||||
Other businesses and corporate |
147 | 280 | ||||||||
Total sales and other operating revenues |
55,863 | 38,512 | ||||||||
By geographical area |
||||||||||
US |
21,152 | 13,576 | ||||||||
Non-US |
40,020 | 27,146 | ||||||||
61,172 | 40,722 | |||||||||
Less: sales and other operating revenues between areas |
5,309 | 2,210 | ||||||||
55,863 | 38,512 | |||||||||
Depreciation, depletion and amortization | First | First | ||||||||
quarter | quarter | |||||||||
$ million | 2017 | 2016 | ||||||||
Upstream |
||||||||||
US |
1,237 | 1,089 | ||||||||
Non-US |
2,054 | 2,104 | ||||||||
3,291 | 3,193 | |||||||||
Downstream |
||||||||||
US |
216 | 210 | ||||||||
Non-US |
279 | 267 | ||||||||
495 | 477 | |||||||||
Other businesses and corporate |
||||||||||
US |
16 | 15 | ||||||||
Non-US |
40 | 45 | ||||||||
56 | 60 | |||||||||
Total group |
3,842 | 3,730 | ||||||||
Note 5. Production and similar taxes
|
||||||||||
First | First | |||||||||
quarter | quarter | |||||||||
$ million | 2017 | 2016 | ||||||||
US |
36 | 18 | ||||||||
Non-US |
270 | (4) | ||||||||
306 | 14 |
22
Note 6. 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.
First | First | |||||||||
quarter | quarter | |||||||||
$ million | 2017 | 2016 | ||||||||
Results for the period |
||||||||||
Profit (loss) for the period attributable to BP shareholders |
1,449 | (583) | ||||||||
Less: preference dividend |
- | - | ||||||||
Profit (loss) attributable to BP ordinary shareholders |
1,449 | (583) | ||||||||
Number of shares (thousand)(a)(b) |
||||||||||
Basic weighted average number of shares outstanding |
19,518,500 | 18,468,632 | ||||||||
ADS equivalent |
3,253,083 | 3,078,105 | ||||||||
Weighted average number of shares outstanding used to calculate diluted earnings per share |
19,621,566 | 18,468,632 | ||||||||
ADS equivalent |
3,270,261 | 3,078,105 | ||||||||
Shares in issue at period-end |
19,664,528 | 18,635,861 | ||||||||
ADS equivalent |
3,277,421 | 3,105,976 |
(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. |
Note 7. Dividends
Dividends payable
BP today announced an interim dividend of 10.00 cents per ordinary share which is expected to be paid on 23 June 2017 to shareholders and American Depositary Share (ADS) holders on the register on 12 May 2017. The corresponding amount in sterling is due to be announced on 12 June 2017, calculated based on the average of the market exchange rates for the four dealing days commencing on 6 June 2017. Holders of ADSs are expected to receive $0.600 per ADS (less applicable fees). A scrip dividend alternative is available, allowing shareholders to elect to receive their dividend in the form of new ordinary shares and ADS holders in the form of new ADSs. Details of the first quarter dividend and timetable are available at bp.com/dividends and details of the scrip dividend programme are available at bp.com/scrip.
First | First | |||||||||
quarter | quarter | |||||||||
2017 | 2016 | |||||||||
Dividends paid per ordinary share |
||||||||||
cents |
10.000 | 10.000 | ||||||||
pence |
8.159 | 7.012 | ||||||||
Dividends paid per ADS (cents) |
60.00 | 60.00 | ||||||||
Scrip dividends |
||||||||||
Number of shares issued (millions) |
115.1 | 154.4 | ||||||||
Value of shares issued ($ million) |
642 | 739 |
23
Note 8. Net Debt*
Net debt ratio* | First | First | ||||||||
quarter | quarter | |||||||||
$ million | 2017 | 2016 | ||||||||
Gross debt |
61,832 | 54,012 | ||||||||
Fair value (asset) liability of hedges related to finance debt(a) |
597 | (967) | ||||||||
62,429 | 53,045 | |||||||||
Less: cash and cash equivalents |
23,794 | 23,049 | ||||||||
Net debt |
38,635 | 29,996 | ||||||||
Equity |
99,282 | 97,289 | ||||||||
Net debt ratio |
28.0% | 23.6% | ||||||||
Analysis of changes in net debt | First | First | ||||||||
quarter | quarter | |||||||||
$ million | 2017 | 2016 | ||||||||
Opening balance |
||||||||||
Finance debt |
58,300 | 53,168 | ||||||||
Fair value (asset) liability of hedges related to finance debt(a) |
697 | 379 | ||||||||
Less: cash and cash equivalents |
23,484 | 26,389 | ||||||||
Opening net debt |
35,513 | 27,158 | ||||||||
Closing balance |
||||||||||
Finance debt |
61,832 | 54,012 | ||||||||
Fair value (asset) liability of hedges related to finance debt(a) |
597 | (967) | ||||||||
Less: cash and cash equivalents |
23,794 | 23,049 | ||||||||
Closing net debt |
38,635 | 29,996 | ||||||||
Decrease (increase) in net debt |
(3,122) | (2,838) | ||||||||
Movement in cash and cash equivalents |
143 | (3,382) | ||||||||
Net cash outflow (inflow) from financing |
(3,111) | 933 | ||||||||
Other movements |
(66) | 359 | ||||||||
Movement in net debt before exchange effects |
(3,034) | (2,090) | ||||||||
Exchange adjustments |
(88) | (748) | ||||||||
Decrease (increase) in net debt |
(3,122) | (2,838) |
(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 $1,746 million (first quarter 2016 liability of $1,225 million) are not included in the calculation of net debt shown above as hedge accounting is not applied for these instruments. |
Note 9. Inventory valuation
A provision of $499 million was held at 31 March 2017 ($677 million at 31 March 2016) to write inventories down to their net realizable value. The net movement credited to the income statement during the first quarter 2017 was $4 million (first quarter 2016 was a credit of $616 million).
Note 10. Statutory accounts
The financial information shown in this publication, which was approved by the Board of Directors on 1 May 2017, is unaudited and does not constitute statutory financial statements. Audited financial information will be published in BP Annual Report and Form 20-F 2017.
24
Additional information
Capital expenditure*
$ million | First quarter 2017 |
First quarter 2016 |
||||||||
Capital expenditure on a cash basis |
||||||||||
Organic capital expenditure* |
3,538 | 4,478 | ||||||||
Inorganic capital expenditure*(a) |
530 | - | ||||||||
4,068 | 4,478 | |||||||||
$ million | First quarter 2017 |
First quarter 2016 |
||||||||
Organic capital expenditure by segment |
||||||||||
Upstream |
||||||||||
US |
641 | 1,247 | ||||||||
Non-US |
2,339 | 2,809 | ||||||||
2,980 | 4,056 | |||||||||
Downstream |
||||||||||
US |
152 | 119 | ||||||||
Non-US |
320 | 269 | ||||||||
472 | 388 | |||||||||
Other businesses and corporate |
||||||||||
US |
21 | - | ||||||||
Non-US |
65 | 34 | ||||||||
86 | 34 | |||||||||
3,538 | 4,478 | |||||||||
Organic capital expenditure by geographical area |
||||||||||
US |
814 | 1,366 | ||||||||
Non-US |
2,724 | 3,112 | ||||||||
3,538 | 4,478 |
(a) | First quarter 2017 includes amounts paid to purchase an interest in the Zohr gas field in Egypt and in exploration blocks in Senegal. |
25
Non-operating items*
$ million | First quarter 2017 |
First quarter 2016 |
||||||||||
Upstream |
||||||||||||
Impairment and gain (loss) on sale of businesses and fixed assets(a) |
(382) | 4 | ||||||||||
Environmental and other provisions |
- | - | ||||||||||
Restructuring, integration and rationalization costs |
2 | (263) | ||||||||||
Fair value gain (loss) on embedded derivatives |
25 | 13 | ||||||||||
Other(b) |
(5) | (109) | ||||||||||
(360) | (355) | |||||||||||
Downstream |
||||||||||||
Impairment and gain (loss) on sale of businesses and fixed assets |
(11) | 321 | ||||||||||
Environmental and other provisions |
- | - | ||||||||||
Restructuring, integration and rationalization costs |
(65) | (35) | ||||||||||
Fair value gain (loss) on embedded derivatives |
- | - | ||||||||||
Other |
- | - | ||||||||||
(76) | 286 | |||||||||||
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 and fixed assets |
(15) | - | ||||||||||
Environmental and other provisions |
- | - | ||||||||||
Restructuring, integration and rationalization costs |
(8) | (48) | ||||||||||
Fair value gain (loss) on embedded derivatives |
- | - | ||||||||||
Gulf of Mexico oil spill(c) |
(35) | (794) | ||||||||||
Other |
67 | (54) | ||||||||||
9 | (896) | |||||||||||
Total before interest and taxation |
(427) | (965) | ||||||||||
Finance costs(c) |
(126) | (123) | ||||||||||
Total before taxation |
(553) | (1,088) | ||||||||||
Taxation credit (charge) |
248 | 310 | ||||||||||
Total after taxation for period |
(305) | (778) |
(a) | First quarter 2017 relates primarily to an impairment charge arising following the announcement on 3 April 2017 of the agreement to sell the Forties Pipeline System business to INEOS. An impairment reversal of $30 million was also recorded in the quarter in relation to Block KG D6 in India. |
(b) | First quarter 2017 includes a $56-million write-back relating to Block KG D6 in India. |
(c) | See Note 2 for further details regarding costs relating to the Gulf of Mexico oil spill. |
26
Non-GAAP information on fair value accounting effects
$ million | First quarter 2017 |
First quarter 2016 |
||||||||
Favourable (unfavourable) impact relative to managements measure of performance |
||||||||||
Upstream |
246 | (103) | ||||||||
Downstream |
40 | (219) | ||||||||
286 | (322) | |||||||||
Taxation credit (charge) |
(79) | 83 | ||||||||
207 | (239) |
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 the income statement. This is 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 physical commodity contracts to meet certain business requirements, such as the purchase of crude for a refinery or the sale of BPs gas production. Under IFRS these physical 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. In addition, derivative instruments are used to manage the price risk associated with certain future natural gas sales. Gains and losses arising are recognized in the income statement from the time the derivative commodity contract is entered into.
IFRS require 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 that 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 managements internal measure of performance. Under managements 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 certain LNG and oil and gas contracts and gas sales 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 managements 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 managements internal measure of performance, are shown in the table above. A reconciliation to GAAP information is set out below.
$ million | First quarter 2017 |
First quarter 2016 |
||||||||
Upstream |
||||||||||
Replacement cost profit (loss) before interest and tax adjusted for fair value accounting effects |
1,010 | (1,102) | ||||||||
Impact of fair value accounting effects |
246 | (103) | ||||||||
Replacement cost profit (loss) before interest and tax |
1,256 | (1,205) | ||||||||
Downstream |
||||||||||
Replacement cost profit before interest and tax adjusted for fair value accounting effects |
1,666 | 2,099 | ||||||||
Impact of fair value accounting effects |
40 | (219) | ||||||||
Replacement cost profit before interest and tax |
1,706 | 1,880 | ||||||||
Total group |
||||||||||
Profit (loss) before interest and tax adjusted for fair value accounting effects |
2,342 | (103) | ||||||||
Impact of fair value accounting effects |
286 | (322) | ||||||||
Profit (loss) before interest and tax |
2,628 | (425) |
27
Readily marketable inventory* (RMI)
$ million |
31 March 2017 |
31 December 2016 |
||||||||
RMI at fair value |
5,495 | 5,952 | ||||||||
Paid-up RMI* |
2,802 | 2,705 |
Readily marketable inventory (RMI) is oil and oil products inventory held and price risk-managed by BPs integrated supply and trading function (IST) which could be sold to generate funds if required. Paid-up RMI is RMI that BP has paid for.
We believe that disclosing the amounts of RMI and paid-up RMI is useful to investors as it enables them to better understand and evaluate the groups inventories and liquidity position by enabling them to see the level of discretionary inventory held by IST and to see builds or releases of liquid trading inventory.
See the Glossary on page 31 for a more detailed definition of RMI. A reconciliation of total inventory as reported on the group balance sheet to paid-up RMI is provided below.
$ million | 31 March 2017 |
31 December 2016 |
||||||||
Reconciliation of total inventory to paid-up RMI |
||||||||||
Inventories as reported on the group balance sheet |
17,236 | 17,655 | ||||||||
Less: (a) inventories which are not oil and oil products and (b) oil and oil product inventories which are not risk-managed by IST |
(12,228) | (12,131) | ||||||||
RMI on an IFRS basis |
5,008 | 5,524 | ||||||||
Plus: difference between RMI at fair value and RMI on an IFRS basis |
487 | 428 | ||||||||
RMI at fair value |
5,495 | 5,952 | ||||||||
Less: unpaid RMI* at fair value |
(2,693) | (3,247) | ||||||||
Paid-up RMI |
2,802 | 2,705 |
28
Reconciliation of basic earnings per ordinary share to replacement cost (RC) profit (loss) per share and to underlying replacement cost profit (loss) per share
Per ordinary share (cents) | First quarter 2017 |
First quarter 2016 |
||||||||
Profit (loss) for the period |
7.42 | (3.16) | ||||||||
Inventory holding (gains) losses*, before tax |
(0.34) | 0.71 | ||||||||
Taxation charge (credit) on inventory holding gains and losses |
0.15 | (0.18) | ||||||||
Replacement cost profit (loss)* |
7.23 | (2.63) | ||||||||
Net (favourable) unfavourable impact of non-operating items* and fair value accounting effects*, before tax |
1.38 | 7.63 | ||||||||
Taxation charge (credit) on non-operating items and fair value accounting effects |
(0.87) | (2.12) | ||||||||
Underlying replacement cost profit* |
7.74 | 2.88 | ||||||||
Reconciliation of effective tax rate (ETR) to ETR on RC profit or loss and adjusted ETR | ||||||||||
Taxation (charge) credit | ||||||||||
$ million | First quarter 2017 |
First quarter 2016 |
||||||||
Taxation on profit or loss |
(623) | 307 | ||||||||
Taxation on inventory holding gains and losses |
(29) | 34 | ||||||||
Taxation on a RC profit or loss basis |
(594) | 273 | ||||||||
Taxation on non-operating items and fair value accounting effects |
169 | 393 | ||||||||
Adjusted taxation |
(763) | (120) | ||||||||
Effective tax rate | ||||||||||
% | First quarter 2017 |
First quarter 2016 |
||||||||
ETR on profit or loss |
29 | 35 | ||||||||
Adjusted for inventory holding gains or losses |
- | 2 | ||||||||
ETR on RC profit or loss* |
29 | 37 | ||||||||
Adjusted for non-operating items and fair value accounting effects |
4 | (19) | ||||||||
Adjusted ETR* |
33 | 18 |
29
Realizations* and marker prices
First quarter 2017 |
First quarter 2016 |
|||||||||
Average realizations(a) |
||||||||||
Liquids* ($/bbl) |
||||||||||
US |
46.34 | 28.75 | ||||||||
Europe |
53.28 | 31.73 | ||||||||
Rest of World(b) |
51.79 | 29.72 | ||||||||
BP Average(b) |
49.87 | 29.61 | ||||||||
Natural gas ($/mcf) |
||||||||||
US |
2.50 | 1.57 | ||||||||
Europe |
5.40 | 4.30 | ||||||||
Rest of World |
3.85 | 3.31 | ||||||||
BP Average |
3.50 | 2.84 | ||||||||
Total hydrocarbons* ($/boe) |
||||||||||
US |
34.29 | 20.73 | ||||||||
Europe |
46.69 | 29.81 | ||||||||
Rest of World(b) |
37.93 | 24.64 | ||||||||
BP Average(b) |
37.19 | 23.81 | ||||||||
Average oil marker prices ($/bbl) |
||||||||||
Brent |
53.69 | 33.94 | ||||||||
West Texas Intermediate |
51.70 | 33.45 | ||||||||
Western Canadian Select |
38.77 | 22.11 | ||||||||
Alaska North Slope |
53.82 | 33.98 | ||||||||
Mars |
49.59 | 30.14 | ||||||||
Urals (NWE - cif) |
51.88 | 31.66 | ||||||||
Average natural gas marker prices |
||||||||||
Henry Hub gas price(c) ($/mmBtu) |
3.32 | 2.09 | ||||||||
UK Gas - National Balancing Point (p/therm) |
48.19 | 30.42 |
(a) | Based on sales of consolidated subsidiaries only - this excludes equity-accounted entities. |
(b) | Production volume recognition methodology for our Technical Service Contract arrangement in Iraq has been simplified to exclude the impact of oil price movements on lifting imbalances. A minor adjustment has been made to first quarter 2016. There is no impact on the financial results. |
(c) | Henry Hub First of Month Index. |
Exchange rates
First quarter 2017 |
First quarter 2016 |
|||||||||
$/£ average rate for the period |
1.24 | 1.43 | ||||||||
$/£ period-end rate |
1.25 | 1.44 | ||||||||
$/ average rate for the period |
1.07 | 1.10 | ||||||||
$/ period-end rate |
1.07 | 1.14 | ||||||||
Rouble/$ average rate for the period |
58.72 | 74.97 | ||||||||
Rouble/$ period-end rate |
56.01 | 67.31 |
30
Glossary
Non-GAAP measures are provided for investors because they are closely tracked by management to evaluate BPs operating performance and to make financial, strategic and operating decisions.
Adjusted effective tax rate (ETR) is a non-GAAP measure. The adjusted ETR is calculated by dividing taxation on an underlying RC basis excluding the impact of the reduction in the rate of the UK North Sea supplementary charge in the third quarter 2016 by underlying RC profit or loss before tax. Taxation on an underlying RC basis is taxation on a RC basis for the period adjusted for taxation on non-operating items and fair value accounting effects. Information on underlying RC profit or loss is provided below. BP believes it is helpful to disclose the adjusted ETR because this measure may help investors to understand and evaluate, in the same manner as management, the underlying trends in BPs operational performance on a comparable basis, period on period. The nearest equivalent measure on an IFRS basis is the ETR on profit or loss for the period, a reconciliation to GAAP information is provided on page 29.
Capital expenditure is total cash capital expenditure as stated in the condensed group cash flow statement.
Consolidation adjustment - UPII is unrealized profit in inventory arising on inter-segment transactions.
Effective tax rate (ETR) on replacement cost (RC) profit or loss is a non-GAAP measure. The ETR on RC profit or loss is calculated by dividing taxation on a RC basis by RC profit or loss before tax. Information on RC profit or loss is provided below. BP believes it is helpful to disclose the ETR on RC profit or loss because this measure excludes the impact of price changes on the replacement of inventories and allows for more meaningful comparisons between reporting periods. The nearest equivalent measure on an IFRS basis is the ETR on profit or loss for the period, a reconciliation to GAAP information is provided on page 29.
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 is provided on page 27.
Gearing - See Net debt and net debt ratio definition.
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 subset of capital expenditure and is a non-GAAP measure. Inorganic capital expenditure comprises consideration in business combinations and certain other significant investments made by the group. It is reported on a cash basis. BP believes that this measure provides useful information as it allows investors to understand how BPs management invests funds in projects which expand the groups activities through acquisition. Further information and a reconciliation to GAAP information is provided on page 25.
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 operations 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.
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.
31
Glossary (continued)
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.
We are unable to present reconciliations of forward-looking information for net debt ratio to gross debt ratio, because without unreasonable efforts, we are unable to forecast accurately certain adjusting items required to present a meaningful comparable GAAP forward-looking financial measure. These items include fair value asset (liability) of hedges related to finance debt, and the amount of cash and cash equivalents; which are difficult to predict in advance in order to include in a GAAP estimate.
Net wind generation capacity is the sum of the rated capacities of the assets/turbines that have entered into commercial operation, including BPs 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 groups 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 9, 11 and 13, and by segment and type is shown on page 26.
Operating cash flow is net cash provided by (used in) operating activities as stated in the condensed group cash flow statement. When used in the context of a segment rather than the group, the terms refer to the segments share thereof.
Operating cash flow excluding Gulf of Mexico oil spill payments is a non-GAAP measure calculated by excluding post-tax operating cash flows relating to the Gulf of Mexico oil spill as reported in Note 2 from net cash provided by operating activities as reported in the condensed group cash flow statement. The nearest equivalent measure on an IFRS basis is net cash provided by operating activities.
Organic capital expenditure is a subset of capital expenditure and is a non-GAAP measure. Organic capital expenditure comprises capital expenditure less inorganic capital expenditure. BP believes that this measure provides useful information as it allows investors to understand how BPs management invests funds in developing and maintaining the groups assets. An analysis of organic capital expenditure by segment and region, and a reconciliation to GAAP information is provided on page 25.
We are unable to present reconciliations of forward-looking information for organic capital expenditure to total cash capital expenditure, because without unreasonable efforts, we are unable to forecast accurately the adjusting item, inorganic capital expenditure, that is difficult to predict in advance in order to derive the nearest GAAP estimate.
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.
Readily marketable inventory (RMI) is inventory held and price risk-managed by our integrated supply and trading function (IST) which could be sold to generate funds if required. It comprises oil and oil products for which liquid markets are available and excludes inventory which is required to meet operational requirements and other inventory which is not price risk-managed. RMI is reported at fair value. Inventory held by the Downstream fuels business for the purpose of sales and marketing, and all inventories relating to the lubricants and petrochemicals businesses, are not included in RMI.
Paid-up RMI excludes RMI which has not yet been paid for. For inventory that is held in storage, a first-in first-out (FIFO) approach is used to determine whether inventory has been paid for or not. Unpaid RMI is RMI which has not yet been paid for by BP. RMI, Paid-up RMI and Unpaid RMI are non-GAAP measures. Further information is provided on page 28.
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.
32
Glossary (continued)
The Refining marker margin (RMM) is the average of regional indicator margins weighted for BPs 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 BPs 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 IFRS. RC profit or loss for the group is not a recognized GAAP measure. BP 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, BPs management believes it is helpful to disclose this measure. The nearest equivalent measure on an IFRS basis is profit or loss attributable to BP shareholders.
RC profit or loss per share is a non-GAAP measure. Earnings per share is defined in Note 6. RC profit or loss per share is calculated using the same denominator. The numerator used is RC profit or loss attributable to BP shareholders rather than profit or loss attributable to BP shareholders. BP believes it is helpful to disclose the RC profit or loss per share because this measure excludes the impact of price changes on the replacement of inventories and allows for more meaningful comparisons between reporting periods. The nearest equivalent measure on an IFRS basis is basic earnings per share based on profit or loss for the period attributable to BP shareholders, a reconciliation to GAAP information is provided on page 29.
Reported recordable injury frequency measures the number of reported work-related employee and contractor incidents that result in a fatality or injury per 200,000 hours worked. This represents reported incidents occurring within BPs operational HSSE reporting boundary. That boundary includes BPs own operated facilities and certain other locations or situations.
Tier 1 process safety events are losses of primary containment from a process of greatest consequence - causing harm to a member of the workforce, costly damage to equipment or exceeding defined quantities. This represents reported incidents occurring within BPs operational HSSE reporting boundary. That boundary includes BPs own operated facilities and certain other locations or situations.
Underlying production is production after adjusting for divestments and entitlement impacts in our production-sharing agreements. 2017 underlying production does not include the Abu Dhabi onshore concession renewal.
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 adjustments for fair value accounting effects are not recognized GAAP measures. See pages 26 and 27 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 BPs 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 BPs 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 attributable to BP shareholders. The nearest equivalent measure on an IFRS basis for segments is RC profit or loss before interest and taxation.
33
Glossary (continued)
Underlying RC profit or loss per share is a non-GAAP measure. Earnings per share is defined in Note 6. Underlying RC profit or loss per share is calculated using the same denominator. The numerator used is underlying RC profit or loss attributable to BP shareholders rather than profit or loss attributable to BP shareholders. BP believes it is helpful to disclose the underlying RC profit or loss per share because this measure may help investors to understand and evaluate, in the same manner as management, the underlying trends in BPs operational performance on a comparable basis, period on period. The nearest equivalent measure on an IFRS basis is basic earnings per share based on profit or loss for the period attributable to BP shareholders, a reconciliation to GAAP information is provided on page 29.
Upstream operating efficiency is calculated as production divided by installed production capacity for BP operated sites, excluding US Lower 48. Installed production capacity is the agreed rate achievable (measured at the export end of the system) when the installed production system (reservoir, wells, plant and export) is fully optimized and operated at full rate with no planned or unplanned deferrals.
Upstream unit production cost is calculated as production cost divided by units of production. Production cost does not include ad valorem and severance taxes. Units of production are barrels for liquids and thousands of cubic feet for gas. Amounts disclosed are for BP subsidiaries only and do not include BPs share of equity-accounted entities.
34
For a full discussion of the groups material legal proceedings, see pages 261-265 of BP Annual Report and Form 20-F 2016.
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, expectations regarding the expected quarterly dividend payment and timing of such payment; expectations regarding 2017 operating cash flow, organic capital expenditure, gearing, and divestment proceeds and the timing thereof; expectations regarding Upstream 2017 underlying production and second-quarter 2017 reported production; expectations regarding Downstream second-quarter 2017 refining margins and turnaround activity; plans and expectations with respect to the start-up of new Upstream projects; expectations with respect to new Upstream production though 2020; plans and expectations regarding development of Downstream markets in Mexico and Indonesia; intention to divest BPs shareholding in SECCO; expectations regarding Rosneft dividends for 2016 and Rosneft operational and financial information for the first quarter of 2017; expectations with respect to the price of Rosnefts acquisition of the Kondaneft project; expectations with respect to the timing and amount of future payments relating to the Gulf of Mexico oil spill; and expectations that claims arising under the 2012 PSC settlement will be substantially paid in 2017; 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; delays in the processes for resolving claims; 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 Rosnefts 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 under Risk factors in BP Annual Report and Form 20-F 2016 as filed with the US Securities and Exchange Commission.
35
Computation of ratio of earnings to fixed charges
| ||||
$ million except ratio | First 2017 | |||
| ||||
Earnings available for fixed charges: |
||||
Pre-tax profit from continuing operations before adjustment for income or loss from joint ventures and associates |
1,759 | |||
Fixed charges |
690 | |||
Amortization of capitalized interest |
58 | |||
Distributed income of joint ventures and associates |
136 | |||
Interest capitalized |
(74) | |||
Non-controlling interest of subsidiaries income not incurring fixed charges |
(4) | |||
|
| |||
Total earnings available for fixed charges |
2,565 | |||
|
| |||
Fixed charges: |
||||
Interest expensed |
296 | |||
Interest capitalized |
74 | |||
Rental expense representative of interest |
320 | |||
|
| |||
Total fixed charges |
690 | |||
|
| |||
Ratio of earnings to fixed charges |
3.72 | |||
|
|
36
The following table shows the unaudited consolidated capitalization and indebtedness of the BP group as of 31 March 2017 in accordance with IFRS:
Capitalization and indebtedness
| ||||
$ million | 31 March 2017 | |||
|
| |||
Share capital and reserves |
||||
Capital shares (1-2) |
5,313 | |||
Paid-in surplus (3) |
13,603 | |||
Merger reserve (3) |
27,206 | |||
Treasury shares |
(17,209) | |||
Available-for-sale investments |
5 | |||
Cash flow hedge reserve |
(1,039) | |||
Foreign currency translation reserve |
(5,759) | |||
Profit and loss account |
75,520 | |||
|
| |||
BP shareholders equity |
97,640 | |||
|
| |||
Finance debt (4-6) |
||||
Due within one year |
7,360 | |||
Due after more than one year |
54,472 | |||
|
| |||
Total finance debt |
61,832 | |||
|
| |||
Total capitalization (7) |
159,472 | |||
|
|
(1) | Issued share capital as of 31 March 2017 comprised 19,675,987,002 ordinary shares, par value US$0.25 per share, and 12,706,252 preference shares, par value £1 per share. This excludes 1,488,795,668 ordinary shares which have been bought back and are held in treasury by BP. These shares are not taken into consideration in relation to the payment of dividends and voting at shareholders meetings. |
(2) | Capital shares represent the ordinary and preference shares of BP which have been issued and are fully paid. |
(3) | Paid-in surplus and merger reserve represent additional paid-in capital of BP which cannot normally be returned to shareholders. |
(4) | Finance debt recorded in currencies other than US dollars has been translated into US dollars at the relevant exchange rates existing on 31 March 2017. |
(5) | Finance debt presented in the table above consists of borrowings and obligations under finance leases. Other contractual obligations are not presented in the table above see BP Annual Report and Form 20-F 2016 Liquidity and capital resources for further information. |
(6) | At 31 March 2017, the parent company, BP p.l.c., had issued guarantees totalling $59,102 million relating to finance debt of subsidiaries. Thus 96% of the groups finance debt had been guaranteed by BP p.l.c. |
At 31 March 2017, $137 million of finance debt was secured by the pledging of assets. The remainder of finance debt was unsecured. |
(7) | At 31 March 2017 the group had issued third-party guarantees under which amounts outstanding, incremental to amounts recognized on the group balance sheet, were $300 million in respect of the borrowings of equity-accounted entities and $263 million in respect of the borrowings of other third parties. |
(8) | There has been no material change since 31 March 2017 in the consolidated capitalization and indebtedness of BP. |
37
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
BP p.l.c.
(Registrant)
Dated: 4 May 2017 | /s/ David J Jackson | |||
David J Jackson | ||||
Company Secretary |
38