3Q25 SEA Part 1 of 1
Top of page 1
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FOR IMMEDIATE RELEASE |
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London 4 November 2025 |
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BP p.l.c. Group results |
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Third quarter and nine months 2025 |
"For a printer friendly version of this announcement please click on the link below to open a PDF version of the announcement"
http://www.rns-pdf.londonstockexchange.com/rns/0057G_1-2025-11-3.pdf
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Strong operations and strategic progress |
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Financial summary |
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Third |
Second |
Third |
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Nine |
Nine |
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quarter |
quarter |
quarter |
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months |
months |
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$ million |
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2025 |
2025 |
2024 |
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2025 |
2024 |
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Profit (loss) for the period attributable to bp shareholders |
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1,161 |
1,629 |
206 |
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3,477 |
2,340 |
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Inventory holding (gains) losses*, net of tax |
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62 |
407 |
906 |
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351 |
362 |
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Replacement cost (RC) profit (loss)* |
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1,223 |
2,036 |
1,112 |
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3,828 |
2,702 |
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Net (favourable) adverse impact of adjusting items*, net of tax |
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987 |
317 |
1,155 |
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2,116 |
5,044 |
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Underlying RC profit* |
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2,210 |
2,353 |
2,267 |
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5,944 |
7,746 |
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Operating cash flow* |
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7,786 |
6,271 |
6,761 |
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16,891 |
19,870 |
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Capital expenditure* |
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(3,381) |
(3,361) |
(4,542) |
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(10,365) |
(12,511) |
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Divestment and other proceeds(a) |
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28 |
1,356 |
290 |
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1,712 |
1,463 |
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Net issue (repurchase) of shares |
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(750) |
(1,063) |
(2,001) |
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(3,660) |
(5,502) |
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Net debt*(b) |
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26,054 |
26,043 |
24,268 |
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26,054 |
24,268 |
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Adjusted EBITDA* |
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9,981 |
9,972 |
9,654 |
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28,654 |
29,599 |
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Underlying operating expenditure* |
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5,487 |
5,457 |
5,590 |
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16,248 |
16,542 |
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Announced dividend per ordinary share (cents per share) |
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8.320 |
8.320 |
8.000 |
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24.640 |
23.270 |
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Underlying RC profit per ordinary share* (cents) |
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14.24 |
15.03 |
13.89 |
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37.98 |
46.79 |
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Underlying RC profit per ADS* (dollars) |
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0.85 |
0.90 |
0.83 |
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2.28 |
2.81 |
Highlights
• Good earnings and cash generation: 3Q25 operating cash flow $7.8bn; stronger underlying earnings across the operating segments supporting 3Q25 underlying RC profit $2.2bn.
• Significant progress in upstream*: 3Q25 upstream plant reliability* 96.8% supporting underlying production* +3% quarter-on-quarter; six major projects* started up in 2025, FID taken on Tiber-Guadalupe in the Gulf of America; 12 exploration discoveries year-to-date.
• Improved reliability and profitability in downstream*: 3Q25 refining availability* increased to 96.6%; around half of Customers & products' share of the group's 2027 structural cost reduction* target now delivered.
• Continued progress on divestments; disciplined capital allocation: Now expect divestment and other proceeds received in 2025 to be above $4 billion. Full year capital expenditure guidance continues to be around $14.5bn with organic capital expenditure* remaining on track to be below $14bn; net debt broadly flat versus prior quarter despite redemption of $1.2bn hybrid bonds.
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"We've delivered another quarter of good performance across the business with operations continuing to run well. All six of the major oil and gas projects planned for 2025 are online, including four ahead of schedule. We've sanctioned our seventh operated production hub in the Gulf of America and have had further exploration success. We delivered record 3Q underlying earnings in customers and refining captured a better margin environment. Meanwhile, we expect full year divestment proceeds to be higher - underpinned by around $5 billion of completed or announced disposal agreements. We continue to make good progress to cut costs, strengthen our balance sheet and increase cash flow and returns. We are looking to accelerate delivery of our plans, including undertaking a thorough review of our portfolio to drive simplification and targeting further improvements in cost performance and efficiency. There is much more to do but we are moving at pace, and demonstrating that bp can and will do better for our investors." |
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Murray Auchincloss Chief executive officer |
(a) Divestment proceeds are disposal proceeds as per the condensed group cash flow statement. See page 3 for more information on other proceeds.
(b) See Note 9 for more information.
RC profit (loss), underlying RC profit, net debt, adjusted EBITDA, underlying operating expenditure, underlying RC profit per ordinary share and underlying RC profit per ADS are non-IFRS measures. Inventory holding (gains) losses and adjusting items are non-IFRS adjustments.
* For items marked with an asterisk throughout this document, definitions are provided in the Glossary on page 31.
Top of page 2
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Highlights |
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3Q25 underlying replacement cost (RC) profit* $2.2 billion |
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Underlying RC profit for the quarter of $2.2 billion, compared with $2.4 billion for the previous quarter, reflects higher profitability in the operating segments offset by a higher underlying effective tax rate (ETR)* in the quarter of 39% which includes changes in the geographical mix of profits. Higher quarter-on-quarter underlying RC profit before interest and tax was driven by significantly lower level of refinery turnaround activity, stronger realized refining margins, and higher production, partly offset by a weak oil trading result, seasonal effects of environmental compliance costs, lower realizations and higher other businesses & corporate underlying charge. |
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Reported profit for the quarter was $1.2 billion, compared with $1.6 billion for the second quarter 2025. The reported result for the third quarter is adjusted for inventory holding losses* of $0.1 billion (net of tax) and a net adverse impact of adjusting items* of $1.0 billion (net of tax) to derive the underlying RC profit. Adjusting items include net impairments and losses on sale of businesses and fixed assets of $0.8 billion (see page 25 for more information on adjusting items). |
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Segment results |
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Gas & low carbon energy: The RC profit before interest and tax for the third quarter 2025 was $1.1 billion, compared with $1.0 billion for the previous quarter. After adjusting RC profit before interest and tax for a net adverse impact of adjusting items of $0.4 billion, the underlying RC profit before interest and tax* for the third quarter was $1.5 billion, compared with $1.5 billion in the second quarter 2025. The third quarter underlying result before interest and tax reflects a lower depreciation, depletion and amortization charge and higher production, partly offset by lower realizations. The gas marketing and trading result was average. |
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Oil production & operations: The RC profit before interest and tax for the third quarter 2025 was $2.1 billion, compared with $1.9 billion for the previous quarter. After adjusting RC profit before interest and tax for a net adverse impact of adjusting items of $0.2 billion, the underlying RC profit before interest and tax for the third quarter was $2.3 billion, compared with $2.3 billion in the second quarter 2025. The third quarter underlying result before interest and tax reflects higher production, primarily in bpx energy, partly offset by higher exploration write-offs. |
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Customers & products: The RC profit before interest and tax for the third quarter 2025 was $1.6 billion, compared with $1.0 billion for the previous quarter. After adjusting RC profit before interest and tax for a net adverse impact of adjusting items of $0.1 billion, the underlying RC profit before interest and tax (underlying result) for the third quarter was $1.7 billion, compared with $1.5 billion in the second quarter 2025. The customers third quarter underlying result was higher by $0.1 billion, reflecting seasonally higher volumes, stronger integrated performance across fuels and midstream, and lower underlying operating expenditure*. The products third quarter underlying result was higher by $0.1 billion, reflecting stronger realized refining margins and a significantly lower level of turnaround activity, partly offset by seasonal effects of environmental compliance costs and the impact of unplanned Whiting outage due to exceptional weather conditions. The oil trading contribution was weak. |
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Operating cash flow* $7.8 billion and net debt* $26.1 billion |
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Operating cash flow of $7.8 billion was around $1.5 billion higher than the previous quarter, reflecting a $0.9 billion working capital* release (after adjusting inventory holding losses, fair value accounting effects and other adjusting items) this quarter compared to a $1.4 billion build in the previous quarter, partly offset by $0.9 billion higher income taxes paid. Net debt was broadly flat at $26.1 billion in the third quarter as higher operating cash flow was partly offset by the redemption of $1.2 billion perpetual hybrid bonds. |
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Financial frame |
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bp is committed to maintaining a strong balance sheet and maintaining 'A' grade credit range through the cycle. We have a target of $14-18 billion of net debt by the end of 2027(a). |
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Our policy is to maintain a resilient dividend. Subject to board approval, we expect an increase in the dividend per ordinary share of at least 4% per year(b). For the third quarter, bp has announced a dividend per ordinary share of 8.320 cents. |
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Share buybacks are a mechanism to return excess cash. When added to the resilient dividend, we expect total shareholder distributions of 30-40% of operating cash flow, over time. Related to the third quarter results, bp intends to execute a $0.75 billion share buyback prior to reporting the fourth quarter results. The $0.75 billion share buyback programme announced with the second quarter results was completed on 31 October 2025. |
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bp will continue to invest with discipline, driven by value and focused on delivering returns. We continue to expect capital expenditure to be around $14.5 billion in 2025. The capital frame of around $13-15 billion for 2026 and 2027 remains unchanged. |
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(a) Potential proceeds from any transactions related to the Castrol strategic review and announcement to bring a strategic partner into Lightsource bp will be allocated to reduce net debt.
(b) Subject to board discretion each quarter taking into account factors including current forecasts, the cumulative level of and outlook for cash flow, share count reduction from buybacks and maintaining 'A' range credit metrics.
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The commentary above contains forward-looking statements and should be read in conjunction with the cautionary statement on page 37. |
Top of page 3
Financial results
In addition to the highlights on page 2:
• Profit attributable to bp shareholders in the third quarter and nine months was $1.2 billion and $3.5 billion respectively, compared with a profit of $0.2 billion and $2.3 billion in the same periods of 2024.
- After adjusting profit attributable to bp shareholders for inventory holding losses* and net impact of adjusting items*, underlying replacement cost (RC) profit* for the third quarter and nine months was $2.2 billion and $5.9 billion respectively, compared with $2.3 billion and $7.7 billion for the same periods of 2024. The underlying RC profit for the third quarter compared with the same period in 2024 mainly reflects higher realized refining margins and lower realizations. The underlying RC profit for the nine months compared with the same period in 2024 mainly reflects lower realizations and a lower gas marketing and trading result, partly offset by stronger performance in customers & products.
- Adjusting items in the third quarter and nine months had a net adverse pre-tax impact of $0.9 billion and $2.0 billion respectively, compared with a net adverse pre-tax impact of $1.6 billion and $5.9 billion in the same periods of 2024.
- Adjusting items for the third quarter and nine months include a favourable pre-tax impact of fair value accounting effects*, relative to management's internal measure of performance, of $0.2 billion and $1.7 billion respectively, compared with a favourable pre-tax impact of $0.4 billion and an adverse pre-tax impact of $0.9 billion in the same periods of 2024. This is primarily due to a decline in the LNG forward price over the 2025 periods compared with an increase in the comparative periods of 2024. In addition there is no significant impact of the fair value accounting effects relating to the hybrid bonds in the third quarter 2025 compared with a favourable impact in the third quarter 2024 and a significantly higher favourable impact of these in the nine months 2025 compared with 2024.
- Adjusting items for the third quarter and nine months of 2025 include an adverse pre-tax impact of asset impairments of $0.4 billion and $1.9 billion respectively, compared with an adverse pre-tax impact of $1.7 billion and $3.7 billion in the same periods of 2024.
• The effective tax rate (ETR) on RC profit or loss* for the third quarter and nine months was 53% and 51% respectively, compared with 51% and 59% for the same periods in 2024. Excluding adjusting items, the underlying ETR* for the third quarter and nine months was 39% and 41%, compared with 42% and 40% for the same periods in 2024. The lower underlying ETR for the third quarter reflects changes in the geographical mix of profits. ETR on RC profit or loss and underlying ETR are non-IFRS measures.
• Operating cash flow* for the third quarter and nine months was $7.8 billion and $16.9 billion respectively, compared with $6.8 billion and $19.9 billion for the same periods in 2024. The change in the operating cash flows reflects the lower tax paid and the lower underlying replacement cost profit before tax for both periods compared with 2024, and differing impact of working capital* movements in the nine months 2025 compared with 2024.
• Capital expenditure* in the third quarter and nine months was $3.4 billion and $10.4 billion respectively, compared with $4.5 billion and $12.5 billion in the same periods of 2024 reflecting the lower capital frame in place for 2025.
• Total divestment and other proceeds for the third quarter and nine months were $28.0 million and $1.7 billion respectively, compared with $0.3 billion and $1.5 billion for the same periods in 2024. Other proceeds for the nine months 2025 were $1.0 billion from the sale of a non-controlling interest in the subsidiary that holds our 12% share in the Trans-Anatolian natural gas pipeline (TANAP). Other proceeds for the nine months 2024 were $0.5 billion from the sale of a 49% interest in a controlled affiliate holding certain midstream assets offshore US.
• At the end of the third quarter, net debt* was $26.1 billion, compared with $26.0 billion at the end of the second quarter 2025 and $24.3 billion at the end of the third quarter 2024. The year on year increase largely reflects lower operating cash flow over the period and acquired net debt, partially offset by the issuance of perpetual hybrid bonds.
Top of page 4
Analysis of RC profit (loss) before interest and tax and reconciliation to profit (loss) for the period
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Third |
Second |
Third |
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Nine |
Nine |
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quarter |
quarter |
quarter |
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months |
months |
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$ million |
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2025 |
2025 |
2024 |
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2025 |
2024 |
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RC profit (loss) before interest and tax |
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gas & low carbon energy |
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1,097 |
1,047 |
1,007 |
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3,502 |
1,728 |
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oil production & operations |
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2,119 |
1,916 |
1,891 |
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6,823 |
8,218 |
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customers & products |
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1,610 |
972 |
23 |
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2,685 |
878 |
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other businesses & corporate |
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(277) |
645 |
653 |
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346 |
173 |
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Consolidation adjustment - UPII* |
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(19) |
30 |
65 |
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24 |
24 |
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RC profit before interest and tax |
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4,530 |
4,610 |
3,639 |
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13,380 |
11,021 |
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Finance costs and net finance expense relating to pensions and other post-employment benefits |
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(1,212) |
(1,173) |
(1,059) |
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(3,654) |
(3,269) |
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Taxation on a RC basis |
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(1,747) |
(1,101) |
(1,304) |
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(4,955) |
(4,541) |
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Non-controlling interests |
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(348) |
(300) |
(164) |
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(943) |
(509) |
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RC profit attributable to bp shareholders* |
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1,223 |
2,036 |
1,112 |
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3,828 |
2,702 |
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Inventory holding gains (losses)* |
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(82) |
(554) |
(1,182) |
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(477) |
(467) |
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Taxation (charge) credit on inventory holding gains and losses |
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20 |
147 |
276 |
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126 |
105 |
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Profit for the period attributable to bp shareholders |
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1,161 |
1,629 |
206 |
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3,477 |
2,340 |
Analysis of underlying RC profit (loss) before interest and tax
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Third |
Second |
Third |
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Nine |
Nine |
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quarter |
quarter |
quarter |
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months |
months |
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$ million |
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2025 |
2025 |
2024 |
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2025 |
2024 |
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Underlying RC profit (loss) before interest and tax |
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gas & low carbon energy |
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1,519 |
1,462 |
1,756 |
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3,978 |
4,816 |
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oil production & operations |
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2,299 |
2,262 |
2,794 |
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7,456 |
9,013 |
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customers & products |
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1,716 |
1,533 |
381 |
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3,926 |
2,819 |
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other businesses & corporate |
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(189) |
(38) |
231 |
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(344) |
(81) |
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Consolidation adjustment - UPII |
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(19) |
30 |
65 |
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24 |
24 |
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Underlying RC profit before interest and tax |
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5,326 |
5,249 |
5,227 |
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15,040 |
16,591 |
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Finance costs on an underlying RC basis(a) and net finance expense relating to pensions and other post-employment benefits |
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(1,129) |
(1,095) |
(1,001) |
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(3,306) |
(2,914) |
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Taxation on an underlying RC basis |
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(1,639) |
(1,501) |
(1,795) |
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(4,847) |
(5,422) |
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Non-controlling interests |
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(348) |
(300) |
(164) |
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(943) |
(509) |
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Underlying RC profit attributable to bp shareholders* |
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2,210 |
2,353 |
2,267 |
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5,944 |
7,746 |
(a) A non-IFRS measure. Finance costs on an underlying RC basis is defined as finance costs as stated in the group income statement excluding finance costs classified as adjusting items* (see footnote (e) on page 25).
Reconciliations of underlying RC profit attributable to bp shareholders to the nearest equivalent IFRS measure are provided on page 1 for the group and on pages 6-12 for the segments.
Operating Metrics
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Third |
Second |
Third |
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Nine |
Nine |
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quarter |
quarter |
quarter |
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months |
months |
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2025 |
2025 |
2024 |
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2025 |
2024 |
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Tier 1 and tier 2 process safety events* |
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7 |
5 |
11 |
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22 |
32 |
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upstream* production(a) (mboe/d) |
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2,362 |
2,300 |
2,378 |
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2,301 |
2,378 |
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upstream unit production costs*(b) ($/boe) |
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6.19 |
6.81 |
6.40 |
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6.44 |
6.25 |
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bp-operated upstream plant reliability* |
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96.8% |
96.8% |
95.0% |
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96.3% |
95.3% |
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bp-operated refining availability*(a) |
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96.6% |
96.4% |
95.6% |
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96.4% |
94.1% |
(a) See Operational updates on pages 6, 8 and 10. Because of rounding, upstream production may not agree exactly with the sum of gas & low carbon energy and oil production & operations.
(b) The increase in the nine months 2025, compared with the nine months 2024 mainly reflects portfolio mix.
Top of page 5
Outlook & Guidance
4Q 2025 guidance
• Looking ahead, bp expects fourth quarter 2025 reported upstream* production to be broadly flat compared with the third quarter 2025. Within this, bp expects reported production from oil production & operations to be slightly higher and production from gas & low carbon energy to be lower.
• In its customers business, bp expects seasonally lower volumes compared to the third quarter and fuels margins to remain sensitive to movements in the cost of supply.
• In products, bp expects, compared to the third quarter, similar level of refinery turnaround activity.
2025 guidance
In addition to the guidance on page 2:
• bp now expects reported upstream* production to be slightly lower and underlying upstream production* to be broadly flat compared with 2024. Within this, bp expects underlying production from oil production & operations to be higher and production from gas & low carbon energy to be lower.
• In its customers business, bp continues to expect growth in its customers businesses including a full year contribution from bp bioenergy. Earnings growth is expected to be supported by structural cost reduction*. bp continues to expect fuels margins to remain sensitive to the cost of supply.
• In products, bp continues to expect stronger underlying performance underpinned by the absence of the plant-wide power outage at Whiting refinery, and improvement plans across the portfolio. bp continues to expect similar levels of refinery turnaround activity, with phasing of turnaround activity in 2025 heavily weighted towards the first half, with the highest impact in the second quarter.
• bp now expects other businesses & corporate underlying annual charge to be around $0.5-0.75 billion for 2025, subject to foreign exchange impacts. The charge may vary from quarter to quarter.
• bp continues to expect the depreciation, depletion and amortization to be slightly higher compared with 2024.
• bp continues to expect the underlying ETR* for 2025 to be around 40% but it is sensitive to a range of factors, including the volatility of the price environment and its impact on the geographical mix of the group's profits and losses.
• bp now expects divestment and other proceeds to be above $4 billion in 2025.
• bp continues to expect Gulf of America settlement payments for the year to be around $1.2 billion pre-tax including $1.1 billion pre-tax paid during the second quarter.
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The commentary above contains forward-looking statements and should be read in conjunction with the cautionary statement on page 37. |
Top of page 6
gas & low carbon energy*
Financial results
• The replacement cost (RC) profit before interest and tax for the third quarter and nine months was $1,097 million and $3,502 million respectively, compared with $1,007 million and $1,728 million for the same periods in 2024. The third quarter and nine months are adjusted by an adverse impact of net adjusting items* of $422 million and $476 million respectively, compared with an adverse impact of net adjusting items of $749 million and $3,088 million for the same periods in 2024. Adjusting items include impacts of fair value accounting effects*, relative to management's internal measure of performance, which are a favourable impact of $131 million and $817 million for the third quarter and nine months in 2025 and an adverse impact of $275 million and $1,173 million for the same periods in 2024. See page 25 for more information on adjusting items.
• After adjusting RC profit before interest and tax for adjusting items, the underlying RC profit before interest and tax* for the third quarter and nine months was $1,519 million and $3,978 million respectively, compared with $1,756 million and $4,816 million for the same periods in 2024.
• The underlying RC profit before interest and tax for the third quarter, compared with the same period in 2024, reflects lower production and lower realizations. The gas marketing and trading result was average.
• The underlying RC profit for the nine months, compared with the same period in 2024, reflects lower production, a lower gas marketing and trading result, and a higher depreciation, depletion and amortization charge, partly offset by lower exploration write-offs and the absence of the foreign exchange loss in Egypt in the first quarter of 2024.
Operational update
• Reported production for the quarter was 806mboe/d, 9.5% lower than the same period in 2024, reflecting the divestments in Egypt and Trinidad in the fourth quarter of 2024. Underlying production* was 0.2% lower due to base decline offset by major project* start-ups in the year.
• Reported production for the nine months was 784mboe/d, 13.0% lower than the same period in 2024, reflecting the divestments in Egypt and Trinidad in the fourth quarter of 2024. Underlying production was 2.8% lower, mainly due to base decline partly offset by major project start-ups in the year.
Strategic progress
gas
• In August, a consortium of bp (16.09%), its Tangguh partners (23.91%), operator EnQuest (40%), and Agra (20%) secured the right to explore the Gaea and Gaea II cover onshore and offshore gas blocks near our Tangguh LNG facility with the signing of government-backed contracts.
• In September bp announced the signing of a memorandum of understanding (MoU) to evaluate opportunities for a five-well programme at water depths ranging from 300 to 1,500 metres in the Mediterranean Sea, offshore Egypt. Drilling operations are expected to start in 2026, with possible tie-back options following evaluation of the drilling campaign and resource potential.
• In September BOTAS and bp signed a three year liquefied natural gas (LNG) purchase agreement to supply 1.6 billion cubic meters (bcm) of LNG annually into Türkiye, totalling 4.8bcm over the contract period.
low carbon energy
• In August JERA Nex bp and EnBW were granted development consent for the 1.5GW Morgan offshore wind project in the Irish Sea from the UK Secretary of State for Energy Security and Net Zero. Morgan is one of three proposed offshore wind projects in the UK, alongside Mona and Morven. Morgan's sister project in the Irish Sea, Mona, received development consent in July. Following deal completion, bp's interests in the projects moved to JERA Nex bp - bp's 50:50 offshore wind joint venture with JERA.
Top of page 7
gas & low carbon energy (continued)
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Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
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$ million |
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2025 |
2025 |
2024 |
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2025 |
2024 |
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Profit before interest and tax |
|
1,097 |
1,047 |
1,007 |
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3,502 |
1,728 |
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Inventory holding (gains) losses* |
|
- |
- |
- |
|
- |
- |
|
RC profit before interest and tax |
|
1,097 |
1,047 |
1,007 |
|
3,502 |
1,728 |
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Net (favourable) adverse impact of adjusting items |
|
422 |
415 |
749 |
|
476 |
3,088 |
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Underlying RC profit before interest and tax |
|
1,519 |
1,462 |
1,756 |
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3,978 |
4,816 |
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Taxation on an underlying RC basis |
|
(529) |
(509) |
(545) |
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(1,509) |
(1,432) |
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Underlying RC profit before interest |
|
990 |
953 |
1,211 |
|
2,469 |
3,384 |
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
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Depreciation, depletion and amortization |
|
|
|
|
|
|
|
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Total depreciation, depletion and amortization |
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1,223 |
1,407 |
1,180 |
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3,796 |
3,682 |
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|
|
|
|
|
|
|
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Exploration write-offs |
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|
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|
|
|
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Exploration write-offs |
|
29 |
1 |
1 |
|
30 |
232 |
|
|
|
|
|
|
|
|
|
|
Adjusted EBITDA* |
|
|
|
|
|
|
|
|
Total adjusted EBITDA |
|
2,771 |
2,870 |
2,937 |
|
7,804 |
8,730 |
|
|
|
|
|
|
|
|
|
|
Capital expenditure* |
|
|
|
|
|
|
|
|
gas(a) |
|
727 |
688 |
1,248 |
|
2,189 |
3,018 |
|
low carbon energy |
|
101 |
102 |
908 |
|
332 |
1,703 |
|
Total capital expenditure(a) |
|
828 |
790 |
2,156 |
|
2,521 |
4,721 |
(a) Comparative periods in 2024 have been restated to reflect the move of our Archaea business from the customers & products segment to the gas & low carbon energy segment.
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
|
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Production (net of royalties)(b) |
|
|
|
|
|
|
|
|
Liquids* (mb/d) |
|
87 |
85 |
92 |
|
85 |
97 |
|
Natural gas (mmcf/d) |
|
4,167 |
4,043 |
4,627 |
|
4,054 |
4,661 |
|
Total hydrocarbons* (mboe/d) |
|
806 |
782 |
890 |
|
784 |
901 |
|
|
|
|
|
|
|
|
|
|
Average realizations*(c) |
|
|
|
|
|
|
|
|
Liquids ($/bbl) |
|
64.57 |
64.15 |
74.80 |
|
66.31 |
77.23 |
|
Natural gas ($/mcf) |
|
6.41 |
6.50 |
5.80 |
|
6.71 |
5.57 |
|
Total hydrocarbons ($/boe) |
|
40.30 |
40.84 |
37.91 |
|
42.06 |
37.13 |
(b) Includes bp's share of production of equity-accounted entities in the gas & low carbon energy segment.
(c) Realizations are based on sales by consolidated subsidiaries only - this excludes equity-accounted entities.
Top of page 8
oil production & operations
Financial results
• The replacement cost (RC) profit before interest and tax for the third quarter and nine months was $2,119 million and $6,823 million respectively, compared with $1,891 million and $8,218 million for the same periods in 2024. The third quarter and nine months are adjusted by an adverse impact of net adjusting items* of $180 million and $633 million respectively, compared with an adverse impact of net adjusting items of $903 million and $795 million for the same periods in 2024. See page 25 for more information on adjusting items.
• After adjusting RC profit before interest and tax for adjusting items, the underlying RC profit before interest and tax* for the third quarter and nine months was $2,299 million and $7,456 million respectively, compared with $2,794 million and $9,013 million for the same periods in 2024.
• The underlying RC profit before interest and tax for the third quarter and nine months, compared with the same periods in 2024, primarily reflects lower realizations and a higher depreciation, depletion and amortization charge, partly offset by higher production and lower exploration write-offs.
Operational update
• Reported production for the quarter was 1,556mboe/d, 4.6% higher than the same period in 2024. Underlying production* for the quarter was 3.5% higher, mainly reflecting higher production in bpx energy.
• Reported production for the nine months was 1,517mboe/d, 2.7% higher than the same period in 2024. Underlying production was 1.9% higher, mainly reflecting higher production in bpx energy.
Strategic progress
• Following the announcement in August regarding an exploration discovery in the Bumerangue block, offshore Brazil, initial laboratory and pressure gradient analysis has confirmed the presence of a ~1,000 metre gross hydrocarbon column including a ~100 metre gross oil column and a ~900 metre gross liquid rich gas-condensate column. Given the presence of liquids across the entire hydrocarbon column, the high-quality rock properties observed and our extensive technology and deepwater developments experience, bp believes that the carbon dioxide in the reservoir can be managed. bp is continuing laboratory testing and other analysis in addition to planning appraisal activities.
• In August Aker BP announced successful completion of the Omega Alfa exploration campaign in the Norwegian North Sea, resulting in a significant oil discovery that adds substantial new resources to the Yggdrasil area. The recoverable volume is estimated at 96-134 million barrels of oil equivalent. The drilling campaign included the three longest well branches ever drilled on the Norwegian continental shelf. First oil from Yggdrasil is expected in 2027.
• In September bp announced it has reached a final investment decision (FID) on the Tiber-Guadalupe project in the Gulf of America. The 100% bp-owned Tiber-Guadalupe will be bp's seventh operated oil and gas production hub in the Gulf of America, featuring a new floating production platform with the capacity to produce 80,000 barrels of crude oil per day. The project includes six wells in the Tiber field and a two-well tieback from the Guadalupe field. Production is expected to start in 2030.
• In October Rhino Resources, operator of the Petroleum Exploration Licence 85 in the Orange Basin offshore Namibia, partnering with Azule Energy (bp's 50% joint venture), announced a discovery at the Volans 1-X well. The well found 26 metres of net pay in rich-gas condensate bearing reservoirs with excellent quality petrophysical properties and a high condensate to gas ratio. This discovery builds on the announcement in April of a discovery in the Capricornus 1-X exploration well in the same licence block.
• In October bp's contract with Iraq's North Oil Company and North Gas Company became effective, after agreeing an initial baseline production rate of 328,000 barrels per day. Under the contract bp will rehabilitate and expand production at the Baba and Avana domes of the Kirkuk field, as well as the Jambour, Bai Hassan, and Khabbaz fields.
• In October bp announced it had safely started up production from the Murlach field in the UK North Sea. The two-well subsea tieback is expected to add a peak net production of around 15,000 barrels of oil equivalent per day. Murlach is bp's sixth major project* start-up in 2025, in line with its strategy to grow the upstream business.
• In October bp agreed to sell its 32% non-operated working interest in the Culzean development in the central North Sea to Serica Energy. The sale is subject to a pre-emption period which runs for 30 days, with each of the Culzean field partners (TotalEnergies, 49.99%, and NEO NEXT, 18.01%) having the option to acquire bp's stake on the same terms as those agreed by Serica.
• In November bp announced that it had reached agreement to divest non-controlling interests in Permian and Eagle Ford midstream assets to investor Sixth Street for $1.5 billion. The transaction is structured in two phases: approximately $1 billion paid upon signing with the balance expected by the end of the year, subject to regulatory approvals.
Top of page 9
oil production & operations (continued)
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Profit before interest and tax |
|
2,116 |
1,914 |
1,889 |
|
6,825 |
8,216 |
|
Inventory holding (gains) losses* |
|
3 |
2 |
2 |
|
(2) |
2 |
|
RC profit before interest and tax |
|
2,119 |
1,916 |
1,891 |
|
6,823 |
8,218 |
|
Net (favourable) adverse impact of adjusting items |
|
180 |
346 |
903 |
|
633 |
795 |
|
Underlying RC profit before interest and tax |
|
2,299 |
2,262 |
2,794 |
|
7,456 |
9,013 |
|
Taxation on an underlying RC basis |
|
(1,054) |
(1,062) |
(1,259) |
|
(3,491) |
(3,939) |
|
Underlying RC profit before interest |
|
1,245 |
1,200 |
1,535 |
|
3,965 |
5,074 |
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Depreciation, depletion and amortization |
|
|
|
|
|
|
|
|
Total depreciation, depletion and amortization |
|
1,961 |
1,933 |
1,708 |
|
5,681 |
5,063 |
|
|
|
|
|
|
|
|
|
|
Exploration write-offs |
|
|
|
|
|
|
|
|
Exploration write-offs |
|
154 |
81 |
309 |
|
288 |
411 |
|
|
|
|
|
|
|
|
|
|
Adjusted EBITDA* |
|
|
|
|
|
|
|
|
Total adjusted EBITDA |
|
4,414 |
4,276 |
4,811 |
|
13,425 |
14,487 |
|
|
|
|
|
|
|
|
|
|
Capital expenditure* |
|
|
|
|
|
|
|
|
Total capital expenditure |
|
1,722 |
1,706 |
1,410 |
|
5,124 |
4,720 |
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
|
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Production (net of royalties)(a) |
|
|
|
|
|
|
|
|
Liquids* (mb/d) |
|
1,121 |
1,115 |
1,084 |
|
1,107 |
1,075 |
|
Natural gas (mmcf/d) |
|
2,525 |
2,338 |
2,348 |
|
2,374 |
2,335 |
|
Total hydrocarbons* (mboe/d) |
|
1,556 |
1,518 |
1,488 |
|
1,517 |
1,477 |
|
|
|
|
|
|
|
|
|
|
Average realizations*(b) |
|
|
|
|
|
|
|
|
Liquids ($/bbl) |
|
59.58 |
59.74 |
70.22 |
|
62.17 |
71.26 |
|
Natural gas ($/mcf) |
|
3.32 |
3.66 |
2.25 |
|
3.87 |
2.32 |
|
Total hydrocarbons ($/boe) |
|
47.89 |
49.03 |
53.65 |
|
50.99 |
54.51 |
(a) Includes bp's share of production of equity-accounted entities in the oil production & operations segment.
(b) Realizations are based on sales by consolidated subsidiaries only - this excludes equity-accounted entities.
Top of page 10
customers & products
Financial results
• The replacement cost (RC) profit before interest and tax for the third quarter and nine months was $1,610 million and $2,685 million respectively, compared with $23 million and $878 million for the same periods in 2024. The third quarter and nine months are adjusted by an adverse impact of net adjusting items* of $106 million and $1,241 million respectively, compared with an adverse impact of net adjusting items of $358 million and $1,941 million for the same periods in 2024. See page 25 for more information on adjusting items.
• After adjusting RC profit before interest and tax for adjusting items, the underlying RC profit before interest and tax* (underlying result) for the third quarter and nine months was $1,716 million and $3,926 million respectively, compared with $381 million and $2,819 million for the same periods in 2024.
• The customers & products underlying result for the third quarter was significantly higher than the same period in 2024, primarily reflecting higher realized refining margins. The result for the nine months was significantly higher than the same period in 2024, reflecting stronger performance both in customers and products.
• customers - the customers underlying result for the third quarter and nine months was higher compared with the same periods in 2024. The underlying result benefited from stronger integrated performance across fuels and midstream, lower underlying operating expenditure* supported by structural cost reductions*, and reflects a more than 20% increase in Castrol's earnings.
• products - the products underlying result for the third quarter was significantly higher compared with the same period in 2024. In refining, the third quarter benefited from significantly higher realized margins and lower turnaround activity, as well as lower underlying operating expenditure. The refining result for the nine months was higher compared with the same period in 2024, primarily driven by the absence of the first quarter 2024 plant-wide power outage at the Whiting refinery and lower underlying operating expenditure, partly offset by lower realized margins and higher turnaround activity. The oil trading contribution for the third quarter and nine months was higher compared with the same periods in 2024.
Operational update
• bp-operated refining availability* for the third quarter and nine months was 96.6% and 96.4%, compared with 95.6% and 94.1% for the same periods in 2024. The nine months was higher reflecting strong performance and notably the absence of the Whiting refinery power outage.
Strategic progress
• Consistent with our strategy to focus downstream and prioritize high-return investments, bp took the decision to stop further work on development of a standalone biofuels production (HEFA) facility at our Rotterdam refinery in the Netherlands.
• Castrol has announced a strategic investment in Electronic Cooling Solutions to expand into full-service thermal management for next-generation AI and high-performance computing systems.
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Profit (loss) before interest and tax |
|
1,531 |
420 |
(1,157) |
|
2,206 |
413 |
|
Inventory holding (gains) losses* |
|
79 |
552 |
1,180 |
|
479 |
465 |
|
RC profit (loss) before interest and tax |
|
1,610 |
972 |
23 |
|
2,685 |
878 |
|
Net (favourable) adverse impact of adjusting items |
|
106 |
561 |
358 |
|
1,241 |
1,941 |
|
Underlying RC profit before interest and tax |
|
1,716 |
1,533 |
381 |
|
3,926 |
2,819 |
|
Of which:(a) |
|
|
|
|
|
|
|
|
customers - convenience & mobility |
|
1,167 |
1,056 |
897 |
|
2,887 |
2,057 |
|
Castrol - included in customers |
|
261 |
245 |
216 |
|
744 |
611 |
|
products - refining & trading |
|
549 |
477 |
(516) |
|
1,039 |
762 |
|
Taxation on an underlying RC basis |
|
(360) |
(251) |
(67) |
|
(687) |
(525) |
|
Underlying RC profit before interest |
|
1,356 |
1,282 |
314 |
|
3,239 |
2,294 |
(a) A reconciliation to RC profit before interest and tax by business is provided on page 29.
Top of page 11
customers & products (continued)
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Adjusted EBITDA*(b) |
|
|
|
|
|
|
|
|
customers - convenience & mobility |
|
1,786 |
1,698 |
1,410 |
|
4,715 |
3,545 |
|
Castrol - included in customers |
|
309 |
295 |
261 |
|
888 |
740 |
|
products - refining & trading |
|
975 |
895 |
(66) |
|
2,301 |
2,120 |
|
|
|
2,761 |
2,593 |
1,344 |
|
7,016 |
5,665 |
|
|
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization |
|
|
|
|
|
|
|
|
Total depreciation, depletion and amortization |
|
1,045 |
1,060 |
963 |
|
3,090 |
2,846 |
|
|
|
|
|
|
|
|
|
|
Capital expenditure* |
|
|
|
|
|
|
|
|
customers - convenience & mobility |
|
386 |
387 |
455 |
|
1,358 |
1,518 |
|
Castrol - included in customers |
|
37 |
36 |
50 |
|
110 |
167 |
|
products - refining & trading(c) |
|
384 |
410 |
416 |
|
1,152 |
1,256 |
|
Total capital expenditure(c) |
|
770 |
797 |
871 |
|
2,510 |
2,774 |
(b) A reconciliation to RC profit before interest and tax by business is provided on page 29.
(c) Comparative periods in 2024 have been restated to reflect the move of our Archaea business from the customers & products segment to the gas & low carbon energy segment.
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
Marketing sales of refined products (mb/d) |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
US |
|
1,273 |
1,248 |
1,240 |
|
1,240 |
1,197 |
|
Europe |
|
1,046 |
1,006 |
1,130 |
|
1,000 |
1,049 |
|
Rest of World |
|
456 |
466 |
457 |
|
463 |
463 |
|
|
|
2,775 |
2,720 |
2,827 |
|
2,703 |
2,709 |
|
Trading/supply sales of refined products |
|
557 |
478 |
354 |
|
492 |
364 |
|
Total sales volume of refined products |
|
3,332 |
3,198 |
3,181 |
|
3,195 |
3,073 |
|
bp average refining indicator margin* (RIM) ($/bbl) |
|
15.8 |
11.9 |
8.7 |
|
12.0 |
11.9 |
|
Refinery throughputs (mb/d) |
|
|
|
|
|
|
|
|
US |
|
683 |
573 |
671 |
|
643 |
622 |
|
Europe |
|
833 |
715 |
769 |
|
790 |
774 |
|
Total refinery throughputs |
|
1,516 |
1,288 |
1,440 |
|
1,433 |
1,396 |
|
|
|
|
|
|
|
|
|
|
bp-operated refining availability* (%) |
|
96.6 |
96.4 |
95.6 |
|
96.4 |
94.1 |
Top of page 12
other businesses & corporate
Other businesses & corporate comprises technology, bp ventures, our corporate activities & functions and any residual costs of the Gulf of America oil spill.
Financial results
• The replacement cost (RC) loss or profit before interest and tax for the third quarter and nine months was a loss of $277 million and a profit of $346 million respectively, compared with a profit of $653 million and $173 million for the same periods in 2024. The third quarter and nine months are adjusted by an adverse impact of net adjusting items* of $88 million and a favourable impact of net adjusting items of $690 million respectively, compared with a favourable impact of net adjusting items of $422 million and $254 million for the same periods in 2024. Adjusting items include adverse impacts of fair value accounting effects* of $13 million for the third quarter and favourable impacts of fair value accounting effects of $1,096 million for the nine months in 2025, and a favourable impact of $494 million and $272 million for the same periods in 2024. See page 25 for more information on adjusting items.
• After adjusting RC loss or profit before interest and tax for adjusting items, the underlying RC loss before interest and tax* for the third quarter and nine months was $189 million and $344 million respectively, compared with a profit of $231 million and a loss of $81 million for the same periods in 2024.
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Profit (loss) before interest and tax |
|
(277) |
645 |
653 |
|
346 |
173 |
|
Inventory holding (gains) losses* |
|
- |
- |
- |
|
- |
- |
|
RC profit (loss) before interest and tax |
|
(277) |
645 |
653 |
|
346 |
173 |
|
Net (favourable) adverse impact of adjusting items(a) |
|
88 |
(683) |
(422) |
|
(690) |
(254) |
|
Underlying RC profit (loss) before interest and tax |
|
(189) |
(38) |
231 |
|
(344) |
(81) |
|
Taxation on an underlying RC basis |
|
106 |
109 |
(64) |
|
248 |
38 |
|
Underlying RC profit (loss) before interest |
|
(83) |
71 |
167 |
|
(96) |
(43) |
(a) Includes fair value accounting effects relating to hybrid bonds. See page 32 for more information.
Top of page 13
Financial statements
Group income statement
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
|
|
|
|
|
|
|
|
|
Sales and other operating revenues (Note 5) |
|
48,420 |
46,627 |
47,254 |
|
141,952 |
143,433 |
|
Earnings from joint ventures - after interest and tax |
|
176 |
241 |
406 |
|
744 |
834 |
|
Earnings from associates - after interest and tax |
|
275 |
155 |
280 |
|
679 |
844 |
|
Interest and other income |
|
397 |
375 |
438 |
|
1,157 |
1,233 |
|
Gains on sale of businesses and fixed assets |
|
(18) |
279 |
(48) |
|
275 |
197 |
|
Total revenues and other income |
|
49,250 |
47,677 |
48,330 |
|
144,807 |
146,541 |
|
Purchases |
|
28,031 |
26,875 |
30,139 |
|
82,626 |
86,677 |
|
Production and manufacturing expenses |
|
6,620 |
6,153 |
5,004 |
|
18,887 |
18,543 |
|
Production and similar taxes |
|
431 |
414 |
469 |
|
1,292 |
1,397 |
|
Depreciation, depletion and amortization (Note 6) |
|
4,472 |
4,641 |
4,117 |
|
13,296 |
12,365 |
|
Net impairment and losses on sale of businesses and fixed assets (Note 3) |
|
753 |
1,157 |
1,842 |
|
2,413 |
3,888 |
|
Exploration expense |
|
224 |
139 |
372 |
|
466 |
798 |
|
Distribution and administration expenses |
|
4,271 |
4,242 |
3,930 |
|
12,924 |
12,319 |
|
Profit (loss) before interest and taxation |
|
4,448 |
4,056 |
2,457 |
|
12,903 |
10,554 |
|
Finance costs |
|
1,267 |
1,229 |
1,101 |
|
3,817 |
3,392 |
|
Net finance (income) expense relating to pensions and other post-employment benefits |
|
(55) |
(56) |
(42) |
|
(163) |
(123) |
|
Profit (loss) before taxation |
|
3,236 |
2,883 |
1,398 |
|
9,249 |
7,285 |
|
Taxation |
|
1,727 |
954 |
1,028 |
|
4,829 |
4,436 |
|
Profit (loss) for the period |
|
1,509 |
1,929 |
370 |
|
4,420 |
2,849 |
|
Attributable to |
|
|
|
|
|
|
|
|
bp shareholders |
|
1,161 |
1,629 |
206 |
|
3,477 |
2,340 |
|
Non-controlling interests |
|
348 |
300 |
164 |
|
943 |
509 |
|
|
|
1,509 |
1,929 |
370 |
|
4,420 |
2,849 |
|
|
|
|
|
|
|
|
|
|
Earnings per share (Note 7) |
|
|
|
|
|
|
|
|
Profit (loss) for the period attributable to bp shareholders |
|
|
|
|
|
|
|
|
Per ordinary share (cents) |
|
|
|
|
|
|
|
|
Basic |
|
7.48 |
10.41 |
1.26 |
|
22.22 |
14.19 |
|
Diluted |
|
7.38 |
10.27 |
1.23 |
|
21.77 |
13.83 |
|
Per ADS (dollars) |
|
|
|
|
|
|
|
|
Basic |
|
0.45 |
0.62 |
0.08 |
|
1.33 |
0.85 |
|
Diluted |
|
0.44 |
0.62 |
0.07 |
|
1.31 |
0.83 |
Top of page 14
Condensed group statement of comprehensive income
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
|
|
|
|
|
|
|
|
|
Profit (loss) for the period |
|
1,509 |
1,929 |
370 |
|
4,420 |
2,849 |
|
Other comprehensive income |
|
|
|
|
|
|
|
|
Items that may be reclassified subsequently to profit or loss |
|
|
|
|
|
|
|
|
Currency translation differences(a) |
|
(276) |
1,323 |
838 |
|
1,866 |
248 |
|
Exchange (gains) losses on translation of foreign operations reclassified to gain or loss on sale of businesses and fixed assets |
|
22 |
- |
- |
|
22 |
- |
|
Cash flow hedges and costs of hedging |
|
134 |
235 |
(111) |
|
184 |
(326) |
|
Share of items relating to equity-accounted entities, net of tax |
|
(5) |
3 |
(41) |
|
(1) |
(39) |
|
Income tax relating to items that may be reclassified |
|
(3) |
(57) |
91 |
|
(18) |
127 |
|
|
|
(128) |
1,504 |
777 |
|
2,053 |
10 |
|
Items that will not be reclassified to profit or loss |
|
|
|
|
|
|
|
|
Remeasurements of the net pension and other post-employment benefit liability or asset |
|
(447) |
(214) |
(51) |
|
(330) |
(357) |
|
Remeasurements of equity investments |
|
- |
2 |
(8) |
|
1 |
(38) |
|
Cash flow hedges that will subsequently be transferred to the balance sheet |
|
(1) |
2 |
10 |
|
3 |
7 |
|
Income tax relating to items that will not be reclassified(b) |
|
126 |
52 |
12 |
|
83 |
745 |
|
|
|
(322) |
(158) |
(37) |
|
(243) |
357 |
|
Other comprehensive income |
|
(450) |
1,346 |
740 |
|
1,810 |
367 |
|
Total comprehensive income |
|
1,059 |
3,275 |
1,110 |
|
6,230 |
3,216 |
|
Attributable to |
|
|
|
|
|
|
|
|
bp shareholders |
|
726 |
2,883 |
922 |
|
5,165 |
2,705 |
|
Non-controlling interests |
|
333 |
392 |
188 |
|
1,065 |
511 |
|
|
|
1,059 |
3,275 |
1,110 |
|
6,230 |
3,216 |
(a) Second quarter and nine months 2025 are principally affected by movements in the Pound Sterling against the US dollar.
(b) Nine months 2024 includes a $658-million credit in respect of the reduction in the deferred tax liability on defined benefit pension plan surpluses following the reduction in the rate of the authorized surplus payments tax charge in the UK from 35% to 25%.
Top of page 15
Condensed group statement of changes in equity
|
|
|
bp shareholders' |
Non-controlling interests |
Total |
|
|
$ million |
|
equity |
Hybrid bonds |
Other interest |
equity |
|
At 1 January 2025 |
|
59,246 |
16,649 |
2,423 |
78,318 |
|
|
|
|
|
|
|
|
Total comprehensive income |
|
5,165 |
607 |
458 |
6,230 |
|
Dividends |
|
(3,805) |
- |
(386) |
(4,191) |
|
Cash flow hedges transferred to the balance sheet, net of tax |
|
(5) |
- |
- |
(5) |
|
Repurchase of ordinary share capital |
|
(3,261) |
- |
- |
(3,261) |
|
Share-based payments, net of tax |
|
908 |
- |
- |
908 |
|
Share of equity-accounted entities' changes in equity, net of tax |
|
1 |
- |
- |
1 |
|
Issue of perpetual hybrid bonds(a) |
|
- |
500 |
- |
500 |
|
Redemption of perpetual hybrid bonds, net of tax(b) |
|
- |
(1,200) |
- |
(1,200) |
|
Payments on perpetual hybrid bonds |
|
(9) |
(618) |
- |
(627) |
|
Transactions involving non-controlling interests, net of tax(c) |
|
4 |
- |
968 |
972 |
|
At 30 September 2025 |
|
58,244 |
15,938 |
3,463 |
77,645 |
|
|
|
|
|
|
|
|
|
|
bp shareholders' |
Non-controlling interests |
Total |
|
|
$ million |
|
equity |
Hybrid bonds |
Other interest |
equity |
|
At 1 January 2024 |
|
70,283 |
13,566 |
1,644 |
85,493 |
|
|
|
|
|
|
|
|
Total comprehensive income |
|
2,705 |
470 |
41 |
3,216 |
|
Dividends |
|
(3,739) |
- |
(282) |
(4,021) |
|
Cash flow hedges transferred to the balance sheet, net of tax |
|
(8) |
- |
- |
(8) |
|
Repurchase of ordinary share capital |
|
(5,554) |
- |
- |
(5,554) |
|
Share-based payments, net of tax |
|
903 |
- |
- |
903 |
|
Issue of perpetual hybrid bonds |
|
(4) |
1,300 |
- |
1,296 |
|
Redemption of perpetual hybrid bonds, net of tax |
|
9 |
(1,300) |
- |
(1,291) |
|
Payments on perpetual hybrid bonds |
|
- |
(520) |
- |
(520) |
|
Transactions involving non-controlling interests, net of tax |
|
231 |
- |
201 |
432 |
|
At 30 September 2024 |
|
64,826 |
13,516 |
1,604 |
79,946 |
(a) During the nine months 2025 a group subsidiary issued perpetual subordinated hybrid securities of $0.5 billion, the proceeds of which were specifically earmarked to fund BP Alternative Energy Investments Ltd including the funding of Lightsource bp. This transaction resulted in a reduction of net debt and gearing.
(b) In the third quarter 2025, BP Capital Markets p.l.c. exercised its option to redeem $1.2 billion of hybrid bonds.
(c) In the nine months 2025, a group subsidiary that holds a 12% stake in the Trans-Anatolian Natural Gas Pipeline (TANAP), issued $1.0 billion of equity instruments with preferred distributions. The group retains control over the ability to defer these distributions which are not guaranteed, and investors cannot redeem their shares except under specific conditions that are within the group's control.
Top of page 16
Group balance sheet
|
|
|
30 September |
31 December |
|
$ million |
|
2025 |
2024 |
|
Non-current assets |
|
|
|
|
Property, plant and equipment |
|
100,363 |
100,238 |
|
Goodwill |
|
15,114 |
14,888 |
|
Intangible assets |
|
9,007 |
9,646 |
|
Investments in joint ventures |
|
12,392 |
12,291 |
|
Investments in associates |
|
9,910 |
7,741 |
|
Other investments |
|
1,166 |
1,292 |
|
Fixed assets |
|
147,952 |
146,096 |
|
Loans |
|
2,172 |
1,961 |
|
Trade and other receivables |
|
2,372 |
1,815 |
|
Derivative financial instruments |
|
18,207 |
16,114 |
|
Prepayments |
|
545 |
548 |
|
Deferred tax assets |
|
5,702 |
5,403 |
|
Defined benefit pension plan surpluses |
|
7,651 |
7,457 |
|
|
|
184,601 |
179,394 |
|
Current assets |
|
|
|
|
Loans |
|
444 |
223 |
|
Inventories |
|
24,154 |
23,232 |
|
Trade and other receivables |
|
26,169 |
27,127 |
|
Derivative financial instruments |
|
4,525 |
5,112 |
|
Prepayments |
|
1,714 |
2,594 |
|
Current tax receivable |
|
973 |
1,096 |
|
Other investments |
|
139 |
165 |
|
Cash and cash equivalents |
|
34,909 |
39,204 |
|
|
|
93,027 |
98,753 |
|
Assets classified as held for sale (Note 2) |
|
2,831 |
4,081 |
|
|
|
95,858 |
102,834 |
|
Total assets |
|
280,459 |
282,228 |
|
Current liabilities |
|
|
|
|
Trade and other payables |
|
54,625 |
58,411 |
|
Derivative financial instruments |
|
3,694 |
4,347 |
|
Accruals |
|
5,290 |
6,071 |
|
Lease liabilities |
|
2,761 |
2,660 |
|
Finance debt |
|
6,091 |
4,474 |
|
Current tax payable |
|
1,562 |
1,573 |
|
Provisions |
|
5,003 |
3,600 |
|
|
|
79,026 |
81,136 |
|
Liabilities directly associated with assets classified as held for sale (Note 2) |
|
1,334 |
1,105 |
|
|
|
80,360 |
82,241 |
|
Non-current liabilities |
|
|
|
|
Other payables |
|
8,086 |
9,409 |
|
Derivative financial instruments |
|
17,415 |
18,532 |
|
Accruals |
|
1,693 |
1,326 |
|
Lease liabilities |
|
11,868 |
9,340 |
|
Finance debt |
|
54,097 |
55,073 |
|
Deferred tax liabilities |
|
8,432 |
8,428 |
|
Provisions |
|
15,810 |
14,688 |
|
Defined benefit pension plan and other post-employment benefit plan deficits |
|
5,053 |
4,873 |
|
|
|
122,454 |
121,669 |
|
Total liabilities |
|
202,814 |
203,910 |
|
Net assets |
|
77,645 |
78,318 |
|
Equity |
|
|
|
|
bp shareholders' equity |
|
58,244 |
59,246 |
|
Non-controlling interests |
|
19,401 |
19,072 |
|
Total equity |
|
77,645 |
78,318 |
Top of page 17
Condensed group cash flow statement
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Operating activities |
|
|
|
|
|
|
|
|
Profit (loss) before taxation |
|
3,236 |
2,883 |
1,398 |
|
9,249 |
7,285 |
|
Adjustments to reconcile profit (loss) before taxation to net cash provided by operating activities |
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization and exploration expenditure written off |
|
4,655 |
4,723 |
4,427 |
|
13,614 |
13,008 |
|
Net impairment and (gain) loss on sale of businesses and fixed assets |
|
771 |
878 |
1,890 |
|
2,138 |
3,691 |
|
Earnings from equity-accounted entities, less dividends received |
|
192 |
40 |
(196) |
|
32 |
(273) |
|
Net charge for interest and other finance expense, less net interest paid |
|
470 |
126 |
324 |
|
743 |
1,040 |
|
Share-based payments |
|
264 |
215 |
278 |
|
880 |
946 |
|
Net operating charge for pensions and other post-employment benefits, less contributions and benefit payments for unfunded plans |
|
(96) |
(36) |
(52) |
|
(143) |
(118) |
|
Net charge for provisions, less payments |
|
(60) |
666 |
(48) |
|
1,710 |
33 |
|
Movements in inventories and other current and non-current assets and liabilities |
|
494 |
(2,030) |
1,798 |
|
(6,605) |
1,223 |
|
Income taxes paid |
|
(2,140) |
(1,194) |
(3,058) |
|
(4,727) |
(6,965) |
|
Net cash provided by operating activities |
|
7,786 |
6,271 |
6,761 |
|
16,891 |
19,870 |
|
Investing activities |
|
|
|
|
|
|
|
|
Expenditure on property, plant and equipment, intangible and other assets |
|
(3,171) |
(3,236) |
(4,223) |
|
(9,758) |
(11,404) |
|
Acquisitions, net of cash acquired |
|
(52) |
(39) |
(218) |
|
(293) |
(440) |
|
Investment in joint ventures |
|
(128) |
(59) |
(76) |
|
(245) |
(524) |
|
Investment in associates |
|
(30) |
(27) |
(25) |
|
(69) |
(143) |
|
Total cash capital expenditure |
|
(3,381) |
(3,361) |
(4,542) |
|
(10,365) |
(12,511) |
|
Proceeds from disposal of fixed assets |
|
30 |
322 |
16 |
|
644 |
117 |
|
Proceeds from disposal of businesses, net of cash disposed |
|
(2) |
76 |
274 |
|
110 |
840 |
|
Proceeds from loan repayments |
|
48 |
31 |
19 |
|
110 |
59 |
|
Cash provided from investing activities |
|
76 |
429 |
309 |
|
864 |
1,016 |
|
Net cash used in investing activities |
|
(3,305) |
(2,932) |
(4,233) |
|
(9,501) |
(11,495) |
|
Financing activities |
|
|
|
|
|
|
|
|
Net issue (repurchase) of shares (Note 7) |
|
(750) |
(1,063) |
(2,001) |
|
(3,660) |
(5,502) |
|
Lease liability payments |
|
(816) |
(784) |
(703) |
|
(2,327) |
(2,076) |
|
Proceeds from long-term financing |
|
1,028 |
1,155 |
2,401 |
|
2,237 |
7,396 |
|
Repayments of long-term financing |
|
(1,250) |
(848) |
(956) |
|
(3,464) |
(2,253) |
|
Net increase (decrease) in short-term debt |
|
104 |
39 |
(73) |
|
18 |
(8) |
|
Issue of perpetual hybrid bonds(a) |
|
- |
- |
- |
|
500 |
1,296 |
|
Redemption of perpetual hybrid bonds(a) |
|
(1,200) |
- |
- |
|
(1,200) |
(1,288) |
|
Payments relating to perpetual hybrid bonds |
|
(284) |
(332) |
(271) |
|
(888) |
(798) |
|
Payments relating to transactions involving non-controlling interests (Other interest) |
|
(2) |
- |
- |
|
(2) |
- |
|
Receipts relating to transactions involving non-controlling interests (Other interest) |
|
8 |
965 |
(7) |
|
973 |
517 |
|
Dividends paid - bp shareholders |
|
(1,288) |
(1,238) |
(1,297) |
|
(3,783) |
(3,720) |
|
- non-controlling interests |
|
(155) |
(127) |
(96) |
|
(356) |
(282) |
|
Net cash provided by (used in) financing activities |
|
(4,605) |
(2,233) |
(3,003) |
|
(11,952) |
(6,718) |
|
Currency translation differences relating to cash and cash equivalents |
|
(51) |
193 |
179 |
|
248 |
(92) |
|
Increase (decrease) in cash and cash equivalents |
|
(175) |
1,299 |
(296) |
|
(4,314) |
1,565 |
|
Cash and cash equivalents at beginning of period |
|
35,130 |
33,831 |
34,891 |
|
39,269 |
33,030 |
|
Cash and cash equivalents at end of period(b) |
|
34,955 |
35,130 |
34,595 |
|
34,955 |
34,595 |
(a) See Condensed group statement of changes in equity - footnotes (a) and (b) for further information.
(b) Third quarter and nine months 2025 includes $46 million (second quarter 2025 $63 million) of cash and cash equivalents classified as assets held for sale in the group balance sheet.
Top of page 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 2024 included in bp Annual Report and Form 20-F 2024.
bp prepares its consolidated financial statements included within bp Annual Report and Form 20-F on the basis of United Kingdom adopted international accounting standards and IFRS Accounting 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 as applicable to companies reporting under international accounting standards. IFRS as adopted by the UK does not differ from IFRS as adopted by the EU. IFRS as adopted by the UK and EU differ 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 2025 which are the same as those used in preparing bp Annual Report and Form 20-F 2024.
There are no new or amended standards or interpretations adopted from 1 January 2025 onwards that have a significant impact on the financial information.
UK Energy Profits Levy
In October 2024, the UK government announced changes (effective from 1 November 2024) to the Energy Profits Levy including a 3% increase in the rate taking the headline rate of tax on North Sea profits to 78%, an extension to the period of application of the Levy to 31 March 2030 and the removal of the Levy's main investment allowance. The changes to the rate and to the investment allowance were substantively enacted in 2024. The extension of the Levy to 31 March 2030 was substantively enacted in the first quarter 2025, resulting in a non-cash deferred charge of $539 million.
Germany tax legislation
On 11 July 2025, the German federal government substantively enacted a number of changes to its tax legislation, including a 5% reduction in the corporate income tax rate by 2032. The reduction in the tax rate will be phased in by means of a 1% reduction each year between 2028 and 2032 and has resulted in a non-cash deferred tax charge of $233 million in the third quarter 2025.
Change in segmentation
During the first quarter of 2025, our Archaea business has moved from the customers & products segment to the gas & low carbon energy segment. The change in segmentation is consistent with a change in the way that resources are allocated, and performance is assessed by the chief operating decision maker, who for bp is the group chief executive.
Comparative information for 2024 has been restated where material to reflect the changes in reportable segments.
Significant accounting judgements and estimates
bp's significant accounting judgements and estimates were disclosed in bp Annual Report and Form 20-F 2024. These have been subsequently considered at the end of this quarter to determine if any changes were required to those judgements and estimates. No significant changes were identified.
Top of page 19
Note 2. Non-current assets held for sale
The carrying amount of assets classified as held for sale at 30 September 2025 is $2,831 million, with associated liabilities of $1,334 million.
Gas & low carbon energy
On 18 July 2025, bp announced that it plans to sell its US onshore wind energy business, bp Wind Energy to LS Power. bp Wind Energy has interests in ten operating onshore wind energy assets across seven US states. The transaction is expected to complete by the end of 2025, subject to regulatory approval. The carrying amount of assets classified as held for sale at 30 September 2025 is $570 million, with associated liabilities of $39 million.
On 24 October 2024, bp completed the acquisition of the remaining 50.03% of Lightsource bp. The acquisition included certain assets for which sales processes were in progress at the acquisition date. Completion of the sale of a significant majority of these assets is expected to complete by the end of 2025, whilst sale of the remaining assets is now expected to complete within the first half of 2026. The carrying amount of assets classified as held for sale at 30 September 2025 is $1,868 million, with associated liabilities of $1,200 million.
On 1 August 2025, bp and JERA Co., Inc. completed formation of a new offshore wind joint venture - JERA Nex bp. bp contributed its development projects in the UK, Germany and US into the joint venture. The related assets and liabilities of those projects, previously classified as held for sale, were derecognised on that date.
Customers & products
On 9 July 2025, bp announced the sale of its Netherlands mobility & convenience and bp pulse businesses to Catom BV. The transaction includes bp's Dutch retail sites, EV charging hubs and the associated fleet business. Completion of the disposal is expected by the end of 2025 subject to regulatory approvals. The carrying amount of assets classified as held for sale at 30 September 2025 is $393 million, with associated liabilities of $95 million.
Note 3. Impairment and losses on sale of businesses and fixed assets
Net impairment charges and losses on sale of businesses and fixed assets for the third quarter and nine months were $753 million and $2,413 million respectively, compared with net charges of $1,842 million and $3,888 million for the same periods in 2024 and include net impairment charges for the third quarter and nine months of $370 million and $1,931 million respectively, compared with net impairment charges of $1,730 million and $3,675 million for the same periods in 2024.
Gas & low carbon energy
Third quarter and nine months 2025 impairments includes a net impairment charge of $135 million and $881 million respectively, compared with net charges of $734 million and $1,859 million for the same periods in 2024 in the gas & low carbon energy segment.
Oil production & operations
Third quarter and nine months 2025 impairments includes a reversal of $7 million and a net impairment charge of $329 million respectively, compared with net charges of $767 million and $900 million for the same periods in 2024 in the oil production & operations segment.
Customers & products
Third quarter and nine months 2025 impairments includes a net impairment charge of $242 million and $719 million respectively, compared with net charges of $223 million and $914 million for the same periods in 2024 in the customers & products segment.
Top of page 20
Note 4. Analysis of replacement cost profit (loss) before interest and tax and reconciliation to profit (loss) before taxation
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
gas & low carbon energy |
|
1,097 |
1,047 |
1,007 |
|
3,502 |
1,728 |
|
oil production & operations |
|
2,119 |
1,916 |
1,891 |
|
6,823 |
8,218 |
|
customers & products |
|
1,610 |
972 |
23 |
|
2,685 |
878 |
|
other businesses & corporate |
|
(277) |
645 |
653 |
|
346 |
173 |
|
|
|
4,549 |
4,580 |
3,574 |
|
13,356 |
10,997 |
|
Consolidation adjustment - UPII* |
|
(19) |
30 |
65 |
|
24 |
24 |
|
RC profit (loss) before interest and tax |
|
4,530 |
4,610 |
3,639 |
|
13,380 |
11,021 |
|
Inventory holding gains (losses)* |
|
|
|
|
|
|
|
|
gas & low carbon energy |
|
- |
- |
- |
|
- |
- |
|
oil production & operations |
|
(3) |
(2) |
(2) |
|
2 |
(2) |
|
customers & products |
|
(79) |
(552) |
(1,180) |
|
(479) |
(465) |
|
Profit (loss) before interest and tax |
|
4,448 |
4,056 |
2,457 |
|
12,903 |
10,554 |
|
Finance costs |
|
1,267 |
1,229 |
1,101 |
|
3,817 |
3,392 |
|
Net finance expense/(income) relating to pensions and other post-employment benefits |
|
(55) |
(56) |
(42) |
|
(163) |
(123) |
|
Profit (loss) before taxation |
|
3,236 |
2,883 |
1,398 |
|
9,249 |
7,285 |
|
|
|
|
|
|
|
|
|
|
RC profit (loss) before interest and tax* |
|
|
|
|
|
|
|
|
US |
|
632 |
1,417 |
1,122 |
|
3,582 |
4,277 |
|
Non-US |
|
3,898 |
3,193 |
2,517 |
|
9,798 |
6,744 |
|
|
|
4,530 |
4,610 |
3,639 |
|
13,380 |
11,021 |
Top of page 21
Note 5. Sales and other operating revenues
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
By segment |
|
|
|
|
|
|
|
|
gas & low carbon energy |
|
9,655 |
9,172 |
8,526 |
|
29,605 |
23,010 |
|
oil production & operations |
|
6,232 |
6,053 |
6,468 |
|
18,787 |
19,559 |
|
customers & products |
|
38,697 |
37,449 |
38,437 |
|
112,309 |
119,432 |
|
other businesses & corporate |
|
627 |
539 |
614 |
|
1,650 |
1,746 |
|
|
|
55,211 |
53,213 |
54,045 |
|
162,351 |
163,747 |
|
|
|
|
|
|
|
|
|
|
Less: sales and other operating revenues between segments |
|
|
|
|
|
|
|
|
gas & low carbon energy |
|
310 |
337 |
385 |
|
1,378 |
1,026 |
|
oil production & operations |
|
5,908 |
5,818 |
5,860 |
|
17,544 |
17,755 |
|
customers & products |
|
70 |
(55) |
(138) |
|
57 |
180 |
|
other businesses & corporate |
|
503 |
486 |
684 |
|
1,420 |
1,353 |
|
|
|
6,791 |
6,586 |
6,791 |
|
20,399 |
20,314 |
|
|
|
|
|
|
|
|
|
|
External sales and other operating revenues |
|
|
|
|
|
|
|
|
gas & low carbon energy |
|
9,345 |
8,835 |
8,141 |
|
28,227 |
21,984 |
|
oil production & operations |
|
324 |
235 |
608 |
|
1,243 |
1,804 |
|
customers & products |
|
38,627 |
37,504 |
38,575 |
|
112,252 |
119,252 |
|
other businesses & corporate |
|
124 |
53 |
(70) |
|
230 |
393 |
|
Total sales and other operating revenues |
|
48,420 |
46,627 |
47,254 |
|
141,952 |
143,433 |
|
|
|
|
|
|
|
|
|
|
By geographical area |
|
|
|
|
|
|
|
|
US |
|
18,968 |
18,890 |
19,388 |
|
56,947 |
59,586 |
|
Non-US |
|
37,877 |
36,233 |
36,712 |
|
109,811 |
112,752 |
|
|
|
56,845 |
55,123 |
56,100 |
|
166,758 |
172,338 |
|
Less: sales and other operating revenues between areas |
|
8,425 |
8,496 |
8,846 |
|
24,806 |
28,905 |
|
|
|
48,420 |
46,627 |
47,254 |
|
141,952 |
143,433 |
|
|
|
|
|
|
|
|
|
|
Revenues from contracts with customers |
|
|
|
|
|
|
|
|
Sales and other operating revenues include the following in relation to revenues from contracts with customers: |
|
|
|
|
|
|
|
|
Crude oil |
|
635 |
421 |
618 |
|
1,471 |
1,704 |
|
Oil products |
|
30,274 |
28,572 |
30,997 |
|
86,008 |
93,385 |
|
Natural gas, LNG and NGLs |
|
7,192 |
6,049 |
6,458 |
|
20,504 |
17,196 |
|
Non-oil products and other revenues from contracts with customers |
|
3,528 |
3,697 |
3,213 |
|
10,858 |
9,249 |
|
Revenue from contracts with customers |
|
41,629 |
38,739 |
41,286 |
|
118,841 |
121,534 |
|
Other operating revenues(a) |
|
6,791 |
7,888 |
5,968 |
|
23,111 |
21,899 |
|
Total sales and other operating revenues |
|
48,420 |
46,627 |
47,254 |
|
141,952 |
143,433 |
(a) Principally relates to commodity derivative transactions including sales of bp own production in trading books.
Top of page 22
Note 6. Depreciation, depletion and amortization
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Total depreciation, depletion and amortization by segment |
|
|
|
|
|
|
|
|
gas & low carbon energy |
|
1,223 |
1,407 |
1,180 |
|
3,796 |
3,682 |
|
oil production & operations |
|
1,961 |
1,933 |
1,708 |
|
5,681 |
5,063 |
|
customers & products |
|
1,045 |
1,060 |
963 |
|
3,090 |
2,846 |
|
other businesses & corporate |
|
243 |
241 |
266 |
|
729 |
774 |
|
|
|
4,472 |
4,641 |
4,117 |
|
13,296 |
12,365 |
|
Total depreciation, depletion and amortization by geographical area |
|
|
|
|
|
|
|
|
US |
|
1,898 |
1,897 |
1,735 |
|
5,531 |
5,008 |
|
Non-US |
|
2,574 |
2,744 |
2,382 |
|
7,765 |
7,357 |
|
|
|
4,472 |
4,641 |
4,117 |
|
13,296 |
12,365 |
Note 7. Earnings per share and shares in issue
Basic earnings per ordinary share (EpS) amounts are calculated by dividing the profit (loss) for the period attributable to ordinary shareholders by the weighted average number of ordinary shares outstanding during the period. Against the authority granted at bp's 2025 annual general meeting, 138 million ordinary shares repurchased were settled during the third quarter 2025 for a total cost of $750 million. All of these shares were held as treasury shares. A further 91 million ordinary shares were repurchased between the end of the reporting period and the date when the financial statements are authorised for issue for a total cost of $522 million. This amount has been accrued at 30 September 2025. The number of shares in issue is reduced when shares are repurchased, but is not reduced in respect of the period-end commitment to repurchase shares subsequent to the end of 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.
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Results for the period |
|
|
|
|
|
|
|
|
Profit (loss) for the period attributable to bp shareholders |
|
1,161 |
1,629 |
206 |
|
3,477 |
2,340 |
|
Less: preference dividend |
|
- |
1 |
- |
|
1 |
1 |
|
Less: (gain) loss on redemption of perpetual hybrid bonds |
|
- |
- |
- |
|
- |
(10) |
|
Profit (loss) attributable to bp ordinary shareholders |
|
1,161 |
1,628 |
206 |
|
3,476 |
2,349 |
|
|
|
|
|
|
|
|
|
|
Number of shares (thousand)(a) |
|
|
|
|
|
|
|
|
Basic weighted average number of shares outstanding |
|
15,518,940 |
15,645,561 |
16,321,349 |
|
15,646,554 |
16,553,408 |
|
ADS equivalent(b) |
|
2,586,490 |
2,607,593 |
2,720,224 |
|
2,607,759 |
2,758,901 |
|
|
|
|
|
|
|
|
|
|
Weighted average number of shares outstanding used to calculate diluted earnings per share |
|
15,735,029 |
15,854,588 |
16,709,108 |
|
15,968,108 |
16,980,519 |
|
ADS equivalent(b) |
|
2,622,504 |
2,642,431 |
2,784,851 |
|
2,661,351 |
2,830,086 |
|
|
|
|
|
|
|
|
|
|
Shares in issue at period-end |
|
15,487,180 |
15,596,112 |
16,155,806 |
|
15,487,180 |
16,155,806 |
|
ADS equivalent(b) |
|
2,581,196 |
2,599,352 |
2,692,634 |
|
2,581,196 |
2,692,634 |
(a) Excludes treasury shares and includes certain shares that will be issued in the future under employee share-based payment plans.
(b) One ADS is equivalent to six ordinary shares.
Top of page 23
Note 8. Dividends
Dividends payable
bp today announced an interim dividend of 8.320 cents per ordinary share which is expected to be paid on 19 December 2025 to ordinary shareholders and American Depositary Share (ADS) holders on the register on 14 November 2025. The ex-dividend date will be 13 November 2025 for ordinary shareholders and 14 November 2025 for ADS holders. The corresponding amount in sterling is due to be announced on 9 December 2025, calculated based on the average of the market exchange rates over three dealing days between 3 December 2025 and 5 December 2025. Holders of ADSs are expected to receive $0.4992 per ADS (less applicable fees). The board has decided not to offer a scrip dividend alternative in respect of the third quarter 2025 dividend. Ordinary shareholders and ADS holders (subject to certain exceptions) will be able to participate in a dividend reinvestment programme. Details of the third quarter dividend and timetable are available at bp.com/dividends and further details of the dividend reinvestment programmes are available at bp.com/drip.
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
|
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Dividends paid per ordinary share |
|
|
|
|
|
|
|
|
cents |
|
8.320 |
8.000 |
8.000 |
|
24.320 |
22.540 |
|
pence |
|
6.194 |
5.899 |
6.050 |
|
18.270 |
17.425 |
|
Dividends paid per ADS (cents) |
|
49.92 |
48.00 |
48.00 |
|
145.92 |
135.24 |
Note 9. Net debt
|
Net debt* |
|
30 September |
30 June |
30 September |
|
$ million |
|
2025 |
2025 |
2024 |
|
Finance debt(a) |
|
60,188 |
60,346 |
57,470 |
|
Fair value (asset) liability of hedges related to finance debt(b) |
|
775 |
764 |
1,393 |
|
|
|
60,963 |
61,110 |
58,863 |
|
Less: cash and cash equivalents |
|
34,909 |
35,067 |
34,595 |
|
Net debt(c) |
|
26,054 |
26,043 |
24,268 |
|
Total equity |
|
77,645 |
79,780 |
79,946 |
|
Gearing* |
|
25.1% |
24.6% |
23.3% |
(a) The fair value of finance debt at 30 September 2025 was $57,113 million (30 June 2025 $57,135 million, 30 September 2024 $54,324 million).
(b) Derivative financial instruments entered into for the purpose of managing foreign currency exchange risk associated with net debt with a fair value liability position of $94 million at 30 September 2025 (second quarter 2025 liability of $96 million and third quarter 2024 liability of $123 million) are not included in the calculation of net debt shown above as hedge accounting is not applied for these instruments.
(c) Net debt does not include accrued interest, which is reported within other receivables and other payables on the balance sheet and for which the associated cash flows are presented as operating cash flows in the group cash flow statement.
Note 10. Events after the reporting period
On 8 October 2025, the International Chamber of Commerce International Court of Arbitration issued a partial final award in bp's favour against Venture Global ("VG"). The arbitration tribunal found that VG had breached its obligations to declare Commercial Operations Date of its Calcasieu Project in a timely manner and act as a "Reasonable and Prudent Operator" pursuant to the long-term LNG Sale and Purchase Agreement ("SPA") with bp. Throughout the breach, VG sold LNG cargos on the spot market rather than to bp as required under the SPA.
The next phase of the arbitration proceedings is a damages hearing, most likely to occur in 2026. Due to the uncertainty of the final amount to be received, management has not recognised a receivable in the quarter.
Note 11. Statutory accounts
The financial information shown in this publication, which was approved by the Board of Directors on 3 November 2025, is unaudited and does not constitute statutory financial statements. Audited financial information will be published in bp Annual Report and Form 20-F 2025. bp Annual Report and Form 20-F 2024 has been filed with the Registrar of Companies in England and Wales. The report of the auditor on those accounts was unqualified, did not include a reference to any matters to which the auditor drew attention by way of emphasis without qualifying the report and did not contain a statement under section 498(2) or section 498(3) of the UK Companies Act 2006.
Top of page 24
Additional information
Capital expenditure*
Capital expenditure is a measure that provides useful information to understand how bp's management allocates resources including the investment of funds in projects which expand the group's activities through acquisition.
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Capital expenditure |
|
|
|
|
|
|
|
|
Organic capital expenditure* |
|
3,328 |
3,321 |
4,341 |
|
10,089 |
11,906 |
|
Inorganic capital expenditure* |
|
53 |
40 |
201 |
|
276 |
605 |
|
|
|
3,381 |
3,361 |
4,542 |
|
10,365 |
12,511 |
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Capital expenditure by segment |
|
|
|
|
|
|
|
|
gas & low carbon energy(a) |
|
828 |
790 |
2,156 |
|
2,521 |
4,721 |
|
oil production & operations |
|
1,722 |
1,706 |
1,410 |
|
5,124 |
4,720 |
|
customers & products(a) |
|
770 |
797 |
871 |
|
2,510 |
2,774 |
|
other businesses & corporate |
|
61 |
68 |
105 |
|
210 |
296 |
|
|
|
3,381 |
3,361 |
4,542 |
|
10,365 |
12,511 |
|
Capital expenditure by geographical area |
|
|
|
|
|
|
|
|
US |
|
1,591 |
1,576 |
1,389 |
|
4,600 |
4,801 |
|
Non-US |
|
1,790 |
1,785 |
3,153 |
|
5,765 |
7,710 |
|
|
|
3,381 |
3,361 |
4,542 |
|
10,365 |
12,511 |
(a) Comparative periods in 2024 have been restated to reflect the move of our Archaea business from the customers & products segment to the gas & low carbon energy segment.
Top of page 25
Adjusting items*
Adjusting items are items that management considers to be important to period-on-period analysis of the group's results and are disclosed in order to enable investors to better understand and evaluate the group's reported financial performance. Adjusting items are used as a reconciling adjustment to derive underlying RC profit or loss and related underlying measures which are non-IFRS measures.
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
gas & low carbon energy |
|
|
|
|
|
|
|
|
Gains on sale of businesses and fixed assets |
|
- |
69 |
19 |
|
68 |
29 |
|
Net impairment and losses on sale of businesses and fixed assets(a) |
|
(489) |
(439) |
(772) |
|
(1,294) |
(1,898) |
|
Environmental and related provisions |
|
- |
- |
- |
|
- |
- |
|
Restructuring, integration and rationalization costs |
|
8 |
3 |
(24) |
|
(3) |
(24) |
|
Fair value accounting effects(b)(c) |
|
131 |
18 |
(275) |
|
817 |
(1,173) |
|
Other |
|
(72) |
(66) |
303 |
|
(64) |
(22) |
|
|
|
(422) |
(415) |
(749) |
|
(476) |
(3,088) |
|
oil production & operations |
|
|
|
|
|
|
|
|
Gains on sale of businesses and fixed assets |
|
(29) |
196 |
(82) |
|
176 |
109 |
|
Net impairment and losses on sale of businesses and fixed assets(a) |
|
10 |
(330) |
(770) |
|
(335) |
(919) |
|
Environmental and related provisions |
|
(145) |
(55) |
(53) |
|
(231) |
65 |
|
Restructuring, integration and rationalization costs |
|
9 |
(46) |
(1) |
|
(78) |
(1) |
|
Fair value accounting effects |
|
- |
- |
- |
|
- |
- |
|
Other |
|
(25) |
(111) |
3 |
|
(165) |
(49) |
|
|
|
(180) |
(346) |
(903) |
|
(633) |
(795) |
|
customers & products |
|
|
|
|
|
|
|
|
Gains on sale of businesses and fixed assets |
|
10 |
16 |
12 |
|
29 |
21 |
|
Net impairment and losses on sale of businesses and fixed assets(a) |
|
(274) |
(389) |
(295) |
|
(777) |
(1,069) |
|
Environmental and related provisions |
|
(1) |
(1) |
(4) |
|
(2) |
3 |
|
Restructuring, integration and rationalization costs |
|
(17) |
(86) |
(39) |
|
(194) |
(38) |
|
Fair value accounting effects(c) |
|
42 |
(201) |
157 |
|
(241) |
38 |
|
Other(d) |
|
134 |
100 |
(189) |
|
(56) |
(896) |
|
|
|
(106) |
(561) |
(358) |
|
(1,241) |
(1,941) |
|
other businesses & corporate |
|
|
|
|
|
|
|
|
Gains on sale of businesses and fixed assets |
|
2 |
- |
3 |
|
2 |
35 |
|
Net impairment and losses on sale of businesses and fixed assets |
|
- |
- |
(6) |
|
(5) |
9 |
|
Environmental and related provisions |
|
(48) |
(18) |
(8) |
|
(138) |
11 |
|
Restructuring, integration and rationalization costs |
|
(8) |
(39) |
(50) |
|
(245) |
(38) |
|
Fair value accounting effects(c) |
|
(13) |
740 |
494 |
|
1,096 |
272 |
|
Gulf of America oil spill |
|
(9) |
(9) |
(20) |
|
(27) |
(39) |
|
Other |
|
(12) |
9 |
9 |
|
7 |
4 |
|
|
|
(88) |
683 |
422 |
|
690 |
254 |
|
Total before interest and taxation |
|
(796) |
(639) |
(1,588) |
|
(1,660) |
(5,570) |
|
Finance costs(e) |
|
(83) |
(78) |
(58) |
|
(348) |
(355) |
|
Total before taxation |
|
(879) |
(717) |
(1,646) |
|
(2,008) |
(5,925) |
|
Taxation on adjusting items(f) |
|
125 |
400 |
535 |
|
664 |
1,229 |
|
Taxation - tax rate change effect(g) |
|
(233) |
- |
(44) |
|
(772) |
(348) |
|
Total after taxation for period |
|
(987) |
(317) |
(1,155) |
|
(2,116) |
(5,044) |
(a) See Note 3 for further information.
(b) Under IFRS bp marks-to-market the value of the hedges used to risk-manage LNG contracts, but not the contracts themselves, resulting in a mismatch in accounting treatment. The fair value accounting effect includes the change in value of LNG contracts that are being risk managed, and the underlying result reflects how bp risk-manages its LNG contracts.
(c) For further information, including the nature of fair value accounting effects reported in each segment, see pages 3, 6 and 32.
(d) Nine months 2024 includes the initial recognition of onerous contract provisions related to Gelsenkirchen refinery. The unwind of these provisions in the subsequent quarters are reported as an adjusting item as the contractual obligations are settled.
(e) Includes the unwinding of discounting effects relating to Gulf of America oil spill payables, the income statement impact of temporary valuation differences related to the group's interest rate and foreign currency exchange risk management associated with finance debt, and the unwinding of discounting effects relating to certain onerous contract provisions.
(f) Includes certain foreign exchange effects on tax as adjusting items. These amounts represent the impact of: (i) foreign exchange on deferred tax balances arising from the conversion of local currency tax base amounts into functional currency, and (ii) taxable gains and losses from the retranslation of US dollar-denominated intra-group loans to local currency.
(g) Third quarter 2025 and nine months 2025 include the deferred tax impact of a change in the tax rate in Germany, see Note 1 for further information. Nine months 2025 and nine months 2024 include revisions to the deferred tax impact of the introduction of the UK Energy Profits Levy (EPL) on temporary differences existing at the opening balance sheet date. The EPL increases the headline rate of tax on
Top of page 26
taxable profits from bp's North Sea business to 78%. In the first quarter 2025 a two-year extension of the EPL to 31 March 2030 was substantively enacted.
Net debt including leases*
Gearing including leases and net debt including leases are non-IFRS measures that provide the impact of the group's lease portfolio on net debt and gearing.
|
Net debt including leases |
|
30 September |
30 June |
30 September |
|
$ million |
|
2025 |
2025 |
2024 |
|
Net debt* |
|
26,054 |
26,043 |
24,268 |
|
Lease liabilities |
|
14,629 |
14,636 |
11,018 |
|
Net partner (receivable) payable for leases entered into on behalf of joint operations |
|
(1,082) |
(1,030) |
(98) |
|
Net debt including leases |
|
39,601 |
39,649 |
35,188 |
|
Total equity |
|
77,645 |
79,780 |
79,946 |
|
Gearing including leases* |
|
33.8% |
33.2% |
30.6% |
Gulf of America oil spill
|
|
|
30 September |
31 December |
|
$ million |
|
2025 |
2024 |
|
Gulf of America oil spill payables and provisions |
|
(7,172) |
(7,958) |
|
Of which - current |
|
(1,512) |
(1,127) |
|
|
|
|
|
|
Deferred tax asset |
|
1,097 |
1,205 |
During the second quarter pre-tax payments of $1,129 million were made relating to the 2016 consent decree and settlement agreement with the United States and the five Gulf coast states. Payables and provisions presented in the table above reflect the latest estimate for the remaining costs associated with the Gulf of America oil spill. Where amounts have been provided on an estimated basis, the amounts ultimately payable may differ from the amounts provided and the timing of payments is uncertain. Further information relating to the Gulf of America oil spill, including information on the nature and expected timing of payments relating to provisions and other payables, is provided in bp Annual Report and Form 20-F 2024 - Financial statements - Notes 7, 22, 23, 29, and 33.
Working capital* reconciliation
Change in working capital adjusted for inventory holding gains/losses*, fair value accounting effects* relating to subsidiaries and other adjusting items is a non-IFRS measure. It represents what would have been reported as movements in inventories and other current and non-current assets and liabilities, if the starting point in determining net cash provided by operating activities had been underlying replacement cost profit rather than profit for the period.
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Movements in inventories and other current and non-current assets and liabilities as per condensed group cash flow statement(a) |
|
494 |
(2,030) |
1,798 |
|
(6,605) |
1,223 |
|
Adjusted for inventory holding gains (losses) (Note 4) |
|
(82) |
(554) |
(1,182) |
|
(477) |
(467) |
|
Adjusted for fair value accounting effects relating to subsidiaries |
|
177 |
554 |
319 |
|
1,690 |
(1,026) |
|
Other adjusting items(b) |
|
322 |
646 |
451 |
|
1,569 |
(201) |
|
Working capital release (build) after adjusting for net inventory holding gains (losses), fair value accounting effects and other adjusting items |
|
911 |
(1,384) |
1,386 |
|
(3,823) |
(471) |
(a) The movement in working capital includes outflows relating to the Gulf of America oil spill on a pre-tax basis of $5 million and $1,136 million in the third quarter and nine months 2025 (second quarter 2025 $1,129 million, third quarter 2024 $4 million, nine months 2024 $1,140 million).
(b) Other adjusting items relate to the non-cash movement of US emissions obligations carried as a provision that will be settled by allowances held as inventory.
Top of page 27
Adjusted earnings before interest, taxation, depreciation and amortization (adjusted EBITDA)*
Adjusted EBITDA is a non-IFRS measure closely tracked by bp's management to evaluate the underlying trends in bp's operating performance on a comparable basis, period on period.
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Profit for the period |
|
1,509 |
1,929 |
370 |
|
4,420 |
2,849 |
|
Finance costs |
|
1,267 |
1,229 |
1,101 |
|
3,817 |
3,392 |
|
Net finance (income) expense relating to pensions and other post-employment benefits |
|
(55) |
(56) |
(42) |
|
(163) |
(123) |
|
Taxation |
|
1,727 |
954 |
1,028 |
|
4,829 |
4,436 |
|
Profit before interest and tax |
|
4,448 |
4,056 |
2,457 |
|
12,903 |
10,554 |
|
Inventory holding (gains) losses*, before tax |
|
82 |
554 |
1,182 |
|
477 |
467 |
|
RC profit before interest and tax |
|
4,530 |
4,610 |
3,639 |
|
13,380 |
11,021 |
|
Net (favourable) adverse impact of adjusting items*, before interest and tax |
|
796 |
639 |
1,588 |
|
1,660 |
5,570 |
|
Underlying RC profit before interest and tax |
|
5,326 |
5,249 |
5,227 |
|
15,040 |
16,591 |
|
Add back: |
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization |
|
4,472 |
4,641 |
4,117 |
|
13,296 |
12,365 |
|
Exploration expenditure written off |
|
183 |
82 |
310 |
|
318 |
643 |
|
Adjusted EBITDA |
|
9,981 |
9,972 |
9,654 |
|
28,654 |
29,599 |
Top of page 28
Underlying operating expenditure* reconciliation
Underlying operating expenditure is a non-IFRS measure and a subset of production and manufacturing expenses plus distribution and administration expenses and excludes costs that are classified as adjusting items. It represents the majority of the remaining expenses in these line items but excludes certain costs that are variable, primarily with volumes (such as freight costs).
Management believes that underlying operating expenditure is a performance measure that provides investors with useful information regarding the company's financial performance because it considers these expenses to be the principal operating and overhead expenses that are most directly under their control although they also include certain foreign exchange and commodity price effects.
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
From group income statement |
|
|
|
|
|
|
|
|
Production and manufacturing expenses |
|
6,620 |
6,153 |
5,004 |
|
18,887 |
18,543 |
|
Distribution and administration expenses |
|
4,271 |
4,242 |
3,930 |
|
12,924 |
12,319 |
|
|
|
10,891 |
10,395 |
8,934 |
|
31,811 |
30,862 |
|
Less certain variable costs: |
|
|
|
|
|
|
|
|
Transportation and shipping costs |
|
2,579 |
2,634 |
2,426 |
|
7,659 |
7,516 |
|
Environmental costs |
|
1,290 |
1,630 |
1,210 |
|
4,257 |
3,078 |
|
Marketing and distribution costs |
|
358 |
421 |
400 |
|
1,206 |
1,532 |
|
Commission, storage and handling costs |
|
410 |
405 |
393 |
|
1,181 |
1,144 |
|
Other variable costs and non-cash costs |
|
654 |
435 |
(602) |
|
1,386 |
439 |
|
Certain variable costs and non-cash costs |
|
5,291 |
5,525 |
3,827 |
|
15,689 |
13,709 |
|
|
|
|
|
|
|
|
|
|
Adjusted operating expenditure* |
|
5,600 |
4,870 |
5,107 |
|
16,122 |
17,153 |
|
Less certain adjusting items*: |
|
|
|
|
|
|
|
|
Gulf of America oil spill |
|
9 |
9 |
20 |
|
27 |
39 |
|
Environmental and related provisions |
|
194 |
74 |
65 |
|
371 |
(79) |
|
Restructuring, integration and rationalization costs |
|
8 |
168 |
114 |
|
520 |
101 |
|
Fair value accounting effects - derivative instruments relating to the hybrid bonds |
|
13 |
(740) |
(494) |
|
(1,096) |
(272) |
|
Other certain adjusting items |
|
(111) |
(98) |
(188) |
|
52 |
822 |
|
Certain adjusting items |
|
113 |
(587) |
(483) |
|
(126) |
611 |
|
|
|
|
|
|
|
|
|
|
Underlying operating expenditure |
|
5,487 |
5,457 |
5,590 |
|
16,248 |
16,542 |
Top of page 29
Reconciliation of customers & products RC profit before interest and tax to underlying RC profit before interest and tax* to adjusted EBITDA* by business
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
$ million |
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
RC profit (loss) before interest and tax for customers & products |
|
1,610 |
972 |
23 |
|
2,685 |
878 |
|
Less: Adjusting items* gains (charges) |
|
(106) |
(561) |
(358) |
|
(1,241) |
(1,941) |
|
Underlying RC profit (loss) before interest and tax for customers & products |
|
1,716 |
1,533 |
381 |
|
3,926 |
2,819 |
|
By business: |
|
|
|
|
|
|
|
|
customers - convenience & mobility |
|
1,167 |
1,056 |
897 |
|
2,887 |
2,057 |
|
Castrol - included in customers |
|
261 |
245 |
216 |
|
744 |
611 |
|
products - refining & trading |
|
549 |
477 |
(516) |
|
1,039 |
762 |
|
|
|
|
|
|
|
|
|
|
Add back: Depreciation, depletion and amortization |
|
1,045 |
1,060 |
963 |
|
3,090 |
2,846 |
|
By business: |
|
|
|
|
|
|
|
|
customers - convenience & mobility |
|
619 |
642 |
513 |
|
1,828 |
1,488 |
|
Castrol - included in customers |
|
48 |
50 |
45 |
|
144 |
129 |
|
products - refining & trading |
|
426 |
418 |
450 |
|
1,262 |
1,358 |
|
|
|
|
|
|
|
|
|
|
Adjusted EBITDA for customers & products |
|
2,761 |
2,593 |
1,344 |
|
7,016 |
5,665 |
|
By business: |
|
|
|
|
|
|
|
|
customers - convenience & mobility |
|
1,786 |
1,698 |
1,410 |
|
4,715 |
3,545 |
|
Castrol - included in customers |
|
309 |
295 |
261 |
|
888 |
740 |
|
products - refining & trading |
|
975 |
895 |
(66) |
|
2,301 |
2,120 |
Top of page 30
Realizations* and marker prices
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
|
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
Average realizations(a) |
|
|
|
|
|
|
|
|
Liquids* ($/bbl) |
|
|
|
|
|
|
|
|
US |
|
54.02 |
53.39 |
63.31 |
|
56.32 |
63.83 |
|
Europe |
|
69.15 |
64.62 |
75.45 |
|
69.81 |
80.44 |
|
Rest of World |
|
67.20 |
69.69 |
80.79 |
|
70.36 |
81.39 |
|
bp average |
|
60.02 |
60.16 |
70.68 |
|
62.55 |
71.89 |
|
Natural gas ($/mcf) |
|
|
|
|
|
|
|
|
US |
|
2.41 |
2.52 |
1.18 |
|
2.67 |
1.39 |
|
Europe |
|
11.98 |
13.06 |
12.22 |
|
13.90 |
10.68 |
|
Rest of World |
|
6.41 |
6.50 |
5.80 |
|
6.71 |
5.57 |
|
bp average |
|
5.34 |
5.56 |
4.75 |
|
5.75 |
4.61 |
|
Total hydrocarbons* ($/boe) |
|
|
|
|
|
|
|
|
US |
|
38.91 |
39.51 |
42.18 |
|
41.41 |
42.65 |
|
Europe |
|
69.25 |
68.02 |
74.03 |
|
73.19 |
74.73 |
|
Rest of World |
|
47.62 |
48.44 |
47.57 |
|
49.70 |
47.22 |
|
bp average |
|
45.00 |
45.84 |
46.81 |
|
47.58 |
46.91 |
|
Average oil marker prices ($/bbl) |
|
|
|
|
|
|
|
|
Brent |
|
69.13 |
67.88 |
80.34 |
|
70.93 |
82.79 |
|
West Texas Intermediate |
|
65.07 |
63.81 |
75.28 |
|
66.74 |
77.71 |
|
Western Canadian Select |
|
52.52 |
53.16 |
59.98 |
|
54.66 |
62.22 |
|
Alaska North Slope |
|
70.07 |
68.82 |
78.95 |
|
71.54 |
82.24 |
|
Average natural gas marker prices |
|
|
|
|
|
|
|
|
Henry Hub gas price(b) ($/mmBtu) |
|
3.07 |
3.44 |
2.15 |
|
3.39 |
2.10 |
|
UK Gas - National Balancing Point (p/therm) |
|
79.84 |
84.53 |
81.77 |
|
93.38 |
75.75 |
(a) Based on sales of consolidated subsidiaries only - this excludes equity-accounted entities.
(b) Henry Hub First of Month Index.
Exchange rates
|
|
|
Third |
Second |
Third |
|
Nine |
Nine |
|
|
|
quarter |
quarter |
quarter |
|
months |
months |
|
|
|
2025 |
2025 |
2024 |
|
2025 |
2024 |
|
$/£ average rate for the period |
|
1.35 |
1.34 |
1.30 |
|
1.31 |
1.28 |
|
$/£ period-end rate |
|
1.34 |
1.37 |
1.34 |
|
1.34 |
1.34 |
|
|
|
|
|
|
|
|
|
|
$/€ average rate for the period |
|
1.17 |
1.13 |
1.10 |
|
1.12 |
1.09 |
|
$/€ period-end rate |
|
1.17 |
1.17 |
1.12 |
|
1.17 |
1.12 |
|
|
|
|
|
|
|
|
|
|
$/AUD average rate for the period |
|
0.65 |
0.64 |
0.67 |
|
0.64 |
0.66 |
|
$/AUD period-end rate |
|
0.66 |
0.65 |
0.69 |
|
0.66 |
0.69 |
|
|
|
|
|
|
|
|
|
Top of page 31
Legal proceedings
For a full discussion of the group's material legal proceedings, see pages 218-219 of bp Annual Report and Form 20-F 2024.
Glossary
Non-IFRS measures are provided for investors because they are closely tracked by management to evaluate bp's operating performance and to make financial, strategic and operating decisions. Non-IFRS measures are sometimes referred to as alternative performance measures.
Adjusted EBITDA is a non-IFRS measure presented for bp's operating segments and is defined as replacement cost (RC) profit before interest and tax, adjusting for net adjusting items* before interest and tax, and adding back depreciation, depletion and amortization and exploration write-offs (net of adjusting items). Adjusted EBITDA by business is a further analysis of adjusted EBITDA for the customers & products businesses. bp believes it is helpful to disclose adjusted EBITDA by operating segment and by business because it reflects how the segments measure underlying business delivery. The nearest equivalent measure on an IFRS basis for the segment is RC profit or loss before interest and tax, which is bp's measure of profit or loss that is required to be disclosed for each operating segment under IFRS. A reconciliation to IFRS information is provided on page 29 for the customers & products businesses.
Adjusted EBITDA for the group is defined as profit or loss for the period, adjusting for finance costs and net finance (income) or expense relating to pensions and other post-employment benefits and taxation, inventory holding gains or losses before tax, net adjusting items before interest and tax, and adding back depreciation, depletion and amortization (pre-tax) and exploration expenditure written-off (net of adjusting items, pre-tax). The nearest equivalent measure on an IFRS basis for the group is profit or loss for the period. A reconciliation to IFRS information is provided on page 27 for the group.
Adjusted operating expenditure is a non-IFRS measure and a subset of production and manufacturing expenses plus distribution and administration expenses. It represents the majority of the remaining expenses in these line items but excludes certain costs that are variable, primarily with volumes (such as freight costs). Other variable costs are included in purchases in the income statement. Management believes that adjusted operating expenditure is a performance measure that provides investors with useful information regarding the company's financial performance because it considers these expenses to be the principal operating and overhead expenses that are most directly under their control although they also include certain adjusting items*, foreign exchange and commodity price effects. The nearest IFRS measures are production and manufacturing expenses and distributions and administration expenses. A reconciliation of production and manufacturing expenses plus distribution and administration expenses to adjusted operating expenditure is provided on page 28.
Adjusting items are items that bp discloses separately because it considers such disclosures to be meaningful and relevant to investors. They are items that management considers to be important to period-on-period analysis of the group's results and are disclosed in order to enable investors to better understand and evaluate the group's reported financial performance. Adjusting items include gains and losses on the sale of businesses and fixed assets, impairments, environmental and related provisions and charges, restructuring, integration and rationalization costs, fair value accounting effects and costs relating to the Gulf of America oil spill and other items. Adjusting items within equity-accounted earnings are reported net of incremental income tax reported by the equity-accounted entity. Adjusting items are used as a reconciling adjustment to derive underlying RC profit or loss and related underlying measures which are non-IFRS measures. An analysis of adjusting items by segment and type is shown on page 25.
Capital expenditure is total cash capital expenditure as stated in the condensed group cash flow statement. Capital expenditure for the operating segments, gas & low carbon energy businesses and customers & products businesses is presented on the same basis.
Consolidation adjustment - UPII is unrealized profit in inventory arising on inter-segment transactions.
Divestment proceeds are disposal proceeds as per the condensed group cash flow statement.
downstream is the customers & products segment.
Effective tax rate (ETR) on replacement cost (RC) profit or loss is a non-IFRS measure. The ETR on RC profit or loss is calculated by dividing taxation on a RC basis by RC profit or loss before tax. Taxation on a RC basis for the group is calculated as taxation as stated on the group income statement adjusted for taxation on inventory holding gains and losses. 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. Taxation on a RC basis and ETR on RC profit or loss are non-IFRS measures. The nearest equivalent measure on an IFRS basis is the ETR on profit or loss for the period.
Top of page 32
Glossary (continued)
Fair value accounting effects are non-IFRS adjustments to our IFRS profit (loss). They reflect the difference between the way bp manages the economic exposure and internally measures performance of certain activities and the way those activities are measured under IFRS. Fair value accounting effects are included within adjusting items. They relate to certain of the group's commodity, interest rate and currency risk exposures as detailed below. Other than as noted below, the fair value accounting effects described are reported in both the gas & low carbon energy and customer & products segments.
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, other than net realizable value provisions, 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 bp's 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. 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 other transportation, storage capacity, oil and gas processing, liquefied natural gas (LNG) and certain gas and power contracts 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 management's internal measure of performance. 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.
These include:
• Under management's internal measure of performance the inventory, transportation and capacity contracts in question are valued based on fair value using relevant forward prices prevailing at the end of the period.
• Fair value accounting effects also include changes in the fair value of the near-term portions of LNG contracts that fall within bp's risk management framework. LNG contracts are not considered derivatives, because there is insufficient market liquidity, and they are therefore accrual accounted under IFRS. However, oil and natural gas derivative financial instruments used to risk manage the near-term portions of the LNG contracts are fair valued under IFRS. The fair value accounting effect, which is reported in the gas and low carbon energy segment, represents the change in value of LNG contracts that are being risk managed and which is reflected in the underlying result, but not in reported earnings. Management believes that this gives a better representation of performance in each period.
Furthermore, the fair values of derivative instruments used to risk manage certain other oil, gas, power and other contracts, are deferred to match with the underlying exposure. The commodity contracts for business requirements are accounted for on an accruals basis.
In addition, fair value accounting effects include changes in the fair value of derivatives entered into by the group to manage currency exposure and interest rate risks relating to hybrid bonds to their respective first call periods. The hybrid bonds which are classified as equity instruments were recorded in the balance sheet at their issuance date at their USD equivalent issued value. Under IFRS these equity instruments are not remeasured from period to period, and do not qualify for application of hedge accounting. The derivative instruments relating to the hybrid bonds, however, are required to be recorded at fair value with mark to market gains and losses recognized in the income statement. Therefore, measurement differences in relation to the recognition of gains and losses occur. The fair value accounting effect, which is reported in the other businesses & corporate segment, eliminates the fair value gains and losses of these derivative financial instruments that are recognized in the income statement. We believe that this gives a better representation of performance, by more appropriately reflecting the economic effect of these risk management activities, in each period.
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Glossary (continued)
Gas & low carbon energy segment comprises our gas and low carbon businesses. Our gas business includes regions with upstream activities that predominantly produce natural gas, integrated gas and power and gas trading. From the first quarter of 2025 it also includes our Archaea business which prior to that was reported in the customers & products segment. Our low carbon business includes solar, offshore and onshore wind, hydrogen and CCS and power trading. Power trading includes trading of both renewable and non-renewable power.
Gearing and net debt are non-IFRS measures. Net debt is calculated as 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. Net debt does not include accrued interest, which is reported within other receivables and other payables on the balance sheet and for which the associated cash flows are presented as operating cash flows in the group cash flow statement. Gearing is defined as the ratio of net debt to the total of net debt plus total equity. bp believes these measures provide useful information to investors. Net debt enables investors to see the economic effect of finance debt, related hedges and cash and cash equivalents in total. Gearing enables investors to see how significant net debt is relative to total equity. The derivatives are reported on the balance sheet within the headings 'Derivative financial instruments'. The nearest equivalent measures on an IFRS basis are finance debt and finance debt ratio. A reconciliation of finance debt to net debt is provided on page 23.
We are unable to present reconciliations of forward-looking information for net debt or gearing to finance debt and total equity, because without unreasonable efforts, we are unable to forecast accurately certain adjusting items required to present a meaningful comparable IFRS forward-looking financial measure. These items include fair value asset (liability) of hedges related to finance debt and cash and cash equivalents, that are difficult to predict in advance in order to include in an IFRS estimate.
Gearing including leases and net debt including leases are non-IFRS measures. Net debt including leases is calculated as net debt plus lease liabilities, less the net amount of partner receivables and payables relating to leases entered into on behalf of joint operations. Gearing including leases is defined as the ratio of net debt including leases to the total of net debt including leases plus total equity. bp believes these measures provide useful information to investors as they enable investors to understand the impact of the group's lease portfolio on net debt and gearing. The nearest equivalent measures on an IFRS basis are finance debt and finance debt ratio. A reconciliation of finance debt to net debt including leases is provided on page 26.
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 on a cash basis and a non-IFRS 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 bp's management invests funds in projects which expand the group's activities through acquisition. The nearest equivalent measure on an IFRS basis is capital expenditure on a cash basis. Further information and a reconciliation to IFRS information is provided on page 24.
Inventory holding gains and losses are non-IFRS adjustments to our IFRS profit (loss) and 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 of inventories other than for trading inventories, 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 as inventory holding gains and losses 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; and
• an adjustment relating to certain trading inventories that are not price risk managed which relate to a minimum inventory volume that is required to be held to maintain underlying business activities. This adjustment represents the movement in fair value of the inventories due to prices, on a grade by grade basis, during the period. This is calculated from each operation's inventory management system on a monthly basis using the discrete monthly movement in market prices for these inventories.
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 that are price risk-managed. See Replacement cost (RC) profit or loss definition below.
Liquids - Liquids comprises crude oil, condensate and natural gas liquids. For the oil production & operations segment, it also includes bitumen.
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Glossary (continued)
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.
Operating cash flow is net cash provided by (used in) operating activities as stated in the condensed group cash flow statement.
Organic capital expenditure is a non-IFRS measure. Organic capital expenditure comprises capital expenditure on a cash basis less inorganic capital expenditure. bp believes that this measure provides useful information as it allows investors to understand how bp's management invests funds in developing and maintaining the group's assets. The nearest equivalent measure on an IFRS basis is capital expenditure on a cash basis and a reconciliation to IFRS information is provided on page 24.
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 IFRS estimate.
Production-sharing agreement/contract (PSA/PSC) is an arrangement through which an oil and gas 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.
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. For the gas & low carbon energy and oil production & operations segments, realizations include transfers between businesses.
Refining availability represents Solomon Associates' operational availability for bp-operated refineries, 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 mechanical, process and regulatory downtime.
Refining indicator margin (RIM) is a simple indicator of the weighted average of bp's crude slate and product yield as deemed representative for each refinery. Actual margins realized by bp may vary due to a variety of factors, including the actual mix of a crude and product for a given quarter.
Replacement cost (RC) profit or loss / RC profit or loss attributable to bp shareholders reflects the replacement cost of inventories sold in the period and is calculated as profit or loss attributable to bp shareholders, adjusting for inventory holding gains and losses (net of tax). RC profit or loss for the group is not a recognized IFRS 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, bp's 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. A reconciliation to IFRS information is provided on page 1. RC profit or loss before interest and tax is bp's measure of profit or loss that is required to be disclosed for each operating segment under IFRS.
Structural cost reduction is calculated as decreases in underlying operating expenditure* (as defined on page 35) as a result of operational efficiencies, divestments, workforce reductions and other cost saving measures that are expected to be sustainable compared with 2023 levels. The total change between periods in underlying operating expenditure will reflect both structural cost reductions and other changes in spend, including market factors, such as inflation and foreign exchange impacts, as well as changes in activity levels and costs associated with new operations. Estimates of cumulative annual structural cost reduction may be revised depending on whether cost reductions realized in prior periods are determined to be sustainable compared with 2023 levels. Structural cost reductions are stewarded internally to support management's oversight of spending over time.
bp believes this performance measure is useful in demonstrating how management drives cost discipline across the entire organization, simplifying our processes and portfolio and streamlining the way we work. The nearest IFRS measures are production and manufacturing expenses and distributions and administration expenses. A reconciliation of production and manufacturing expenses plus distribution and administration expenses to underlying operating expenditure is provided on page 28.
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Glossary (continued)
Technical service contract (TSC) - Technical service contract is an arrangement through which an oil and gas company bears the risks and costs of exploration, development and production. In return, the oil and gas company receives entitlement to variable physical volumes of hydrocarbons, representing recovery of the costs incurred and a profit margin which reflects incremental production added to the oilfield.
Tier 1 and tier 2 process safety events - Tier 1 events are losses of primary containment from a process of greatest consequence - causing harm to a member of the workforce, damage to equipment from a fire or explosion, a community impact or exceeding defined quantities. Tier 2 events are those of lesser consequence. These represent reported incidents occurring within bp's operational HSSE reporting boundary. That boundary includes bp's own operated facilities and certain other locations or situations. Reported process safety events are investigated throughout the year and as a result there may be changes in previously reported events. Therefore comparative movements are calculated against internal data reflecting the final outcomes of such investigations, rather than the previously reported comparative period, as this represents a more up to date reflection of the safety environment.
Underlying effective tax rate (ETR) is a non-IFRS measure. The underlying ETR is calculated by dividing taxation on an underlying replacement cost (RC) basis by underlying RC profit or loss before tax. Taxation on an underlying RC basis for the group is calculated as taxation as stated on the group income statement adjusted for taxation on inventory holding gains and losses and total taxation on adjusting items. Information on underlying RC profit or loss is provided below. Taxation on an underlying RC basis presented for the operating segments is calculated through an allocation of taxation on an underlying RC basis to each segment. bp believes it is helpful to disclose the underlying ETR because this measure 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. Taxation on an underlying RC basis and underlying ETR are non-IFRS measures. The nearest equivalent measure on an IFRS basis is the ETR on profit or loss for the period.
We are unable to present reconciliations of forward-looking information for underlying ETR to ETR on profit or loss for the period, because without unreasonable efforts, we are unable to forecast accurately certain adjusting items required to present a meaningful comparable IFRS forward-looking financial measure. These items include the taxation on inventory holding gains and losses and adjusting items, that are difficult to predict in advance in order to include in an IFRS estimate.
Underlying operating expenditure is a non-IFRS measure and a subset of production and manufacturing expenses plus distribution and administration expenses and excludes costs that are classified as adjusting items. It represents the majority of the remaining expenses in these line items but excludes certain costs that are variable, primarily with volumes (such as freight costs). Other variable costs are included in purchases in the income statement. Management believes that underlying operating expenditure is a performance measure that provides investors with useful information regarding the company's financial performance because it considers these expenses to be the principal operating and overhead expenses that are most directly under their control although they also include certain foreign exchange and commodity price effects. The nearest IFRS measures are production and manufacturing expenses and distribution and administration expenses. A reconciliation of production and manufacturing expenses plus distribution and administration expenses to underlying operating expenditure is provided on page 28.
Underlying production - 2025 underlying production, when compared with 2024, is production after adjusting for acquisitions and divestments, curtailments, and entitlement impacts in our production-sharing agreements/contracts and technical service contract*.
Underlying RC profit or loss / underlying RC profit or loss attributable to bp shareholders is a non-IFRS measure and is RC profit or loss* (as defined on page 34) after excluding net adjusting items and related taxation. See page 25 for additional information on the adjusting items that are used to arrive at underlying RC profit or loss in order to enable a full understanding of the items and their financial impact.
Underlying RC profit or loss before interest and tax for the operating segments or customers & products businesses is calculated as RC profit or loss (as defined above) including profit or loss attributable to non-controlling interests before interest and tax for the operating segments and excluding net adjusting items for the respective operating segment or business.
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 adjusting items. 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 and businesses is RC profit or loss before interest and taxation. A reconciliation to IFRS information is provided on page 1 for the group and pages 6-12 for the segments.
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Glossary (continued)
Underlying RC profit or loss per share / underlying RC profit or loss per ADS is a non-IFRS measure. Earnings per share is defined in Note 7. Underlying RC profit or loss per ordinary share is calculated using the same denominator as earnings per share as defined in the consolidated financial statements. The numerator used is underlying RC profit or loss attributable to bp shareholders, rather than profit or loss attributable to bp ordinary shareholders. Underlying RC profit or loss per ADS is calculated as outlined above for underlying RC profit or loss per share except the denominator is adjusted to reflect one ADS equivalent to six ordinary shares. bp believes it is helpful to disclose the underlying RC profit or loss per ordinary share and per ADS because these measures 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. The nearest equivalent measure on an IFRS basis is basic earnings per share based on profit or loss for the period attributable to bp ordinary shareholders.
upstream includes oil and natural gas field development and production within the gas & low carbon energy and oil production & operations segments.
upstream/hydrocarbon plant reliability (bp-operated) is calculated taking 100% less the ratio of total unplanned plant deferrals divided by installed production capacity, excluding non-operated assets and bpx energy. Unplanned plant deferrals are associated with the topside plant and where applicable the subsea equipment (excluding wells and reservoir). Unplanned plant deferrals include breakdowns, which does not include Gulf of America weather related downtime.
upstream unit production costs are 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 bp's share of equity-accounted entities.
Working capital is movements in inventories and other current and non-current assets and liabilities as reported in the condensed group cash flow statement.
Change in working capital adjusted for inventory holding gains/losses, fair value accounting effects relating to subsidiaries and other adjusting items is a non-IFRS measure. It is calculated by adjusting for inventory holding gains/losses reported in the period; fair value accounting effects relating to subsidiaries reported within adjusting items for the period; and other adjusting items relating to the non-cash movement of US emissions obligations carried as a provision that will be settled by allowances held as inventory. This represents what would have been reported as movements in inventories and other current and non-current assets and liabilities, if the starting point in determining net cash provided by operating activities had been underlying replacement cost profit rather than profit for the period. The nearest equivalent measure on an IFRS basis for this is movements in inventories and other current and non-current assets and liabilities.
bp utilizes various arrangements in order to manage its working capital including discounting of receivables and, in the supply and trading business, the active management of supplier payment terms, inventory and collateral.
Trade marks
Trade marks of the bp group appear throughout this announcement. They include:
bp, Amoco, Aral, ampm, bp pulse, Castrol, PETRO, TA, and Thorntons
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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') and the general doctrine of cautionary statements, bp is providing the following cautionary statement:
The discussion in this announcement contains certain forecasts, projections and forward-looking statements - that is, statements related to future, not past events and circumstances - 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', 'focus on' or similar expressions.
In particular, the following, among other statements, are all forward-looking in nature: plans, expectations and assumptions regarding oil and gas demand, supply, prices or volatility; expectations regarding production and volumes; expectations regarding turnaround and maintenance activity; plans and expectations regarding bp's balance sheet, financial performance, results of operations, cost reduction, cash flows, and shareholder returns; plans and expectations regarding the amount and timing of dividends, share buybacks, and dividend reinvestment programs; plans and expectations regarding bp's upstream production; plans and expectations regarding the amount, timing, quantum and nature of certain acquisitions, divestments and related payments and proceeds, including expectations regarding bp Wind Energy, Lightsource bp and other bp businesses and assets subject to disposal or divestment; plans and expectations regarding bp's net debt, credit rating, investment strategy, capital expenditures, capital frame, underlying effective tax rate, and depreciation, depletion and amortization; expectations regarding bp's customers business, including with respect to earnings growth, fuels margins and the impact of structural cost reduction; expectations regarding bp's products, including underlying performance and refinery turnaround activity; expectations regarding bp's other businesses & corporate underlying annual charge; expectations regarding Gulf of America settlement payments; plans and expectations regarding the Tiber-Guadalupe project as well as bp's projects in the Mediterranean Sea, the Bumerangue block, the UK's North Sea, and Aker BP's project in the Yggdrasil area; plans and expectations regarding bp's partnerships and other collaborations and agreements with BOTAS, Iraq's North Oil Company and North Gas Company and others; expectations regarding bp's tax liabilities and obligations; and expectations regarding the pending legal proceedings involving bp.
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. Recent global developments have caused significant uncertainty and volatility in macroeconomic conditions and commodity markets. Each item of outlook and guidance set out in this announcement is based on bp's current expectations but actual outcomes and results may be impacted by these evolving macroeconomic and market conditions.
Actual results or outcomes may differ materially from those expressed in such statements, depending on a variety of factors, including: the extent and duration of the impact of current market conditions including the volatility of oil prices, the effects of bp's plan to exit its shareholding in Rosneft and other investments in Russia, overall global economic and business conditions impacting bp's business and demand for bp's products as well as the specific factors identified in the discussions accompanying such forward-looking statements; changes in consumer preferences and societal expectations; the pace of development and adoption of alternative energy solutions; developments in policy, law, regulation, technology and markets, including societal and investor sentiment related to the issue of climate change; the receipt of relevant third party and/or regulatory approvals including ongoing approvals required for the continued developments of approved projects; 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 acquisitions and divestments; future levels of industry product supply, demand and pricing, including supply growth in North America and continued base oil and additive supply shortages; OPEC+ quota restrictions; PSA and TSC 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 and policies, including related to climate change; changes in social attitudes and customer preferences; 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; amounts ultimately payable and timing of payments relating to the Gulf of America oil spill; 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; bp's access to future credit resources; business disruption and crisis management; the impact on bp's reputation of ethical misconduct and non-compliance with regulatory obligations; trading losses; major uninsured losses; the possibility that international sanctions or other steps taken by governmental authorities or any other relevant persons may impact bp's ability to sell its interests in Rosneft, or the price for which bp could sell such interests; 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 those factors discussed under "Principal risks and uncertainties" in bp's Report on Form 6-K regarding results for the six-month period ended 30 June 2025 as filed with the US Securities and Exchange Commission (the "SEC") as well as "Risk factors" in bp's Annual Report and Form 20-F for fiscal year 2024 as filed with the SEC.
Cautionary note to U.S. investors - This document contains references to non-proved reserves and production outlooks based on non-proved reserves that the SEC's rules prohibit us from including in our filings with the SEC. U.S. investors are urged to consider closely the disclosures in our Form 20-F, SEC File No. 1-06262. This form is available on our website at www.bp.com. You can also obtain this form from the SEC's website at www.sec.gov.
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