Full year and 4Q 2024 financial results

Highlights 

• Financial and operational performance: 2024 Operating cash flow $27.3bn; 2024 Adjusted EBITDA $38.0bn; 2024 upstream production 2,358mmboe/d, 2.0% higher than 2023.
• Driving focus and efficiency: High-grading portfolio, agreed to form offshore wind JV with JERA Co.,Inc, divesting non-core assets. We delivered $0.8 billion structural cost reduction* in 2024.
• Growing our portfolio: FID taken on 10 major projects*, including Tangguh UCC project in Papua Barat, Indonesia; established a new gas joint venture, Arcius Energy with XRG; signed an agreement with ONGC as the technical services provider for the largest offshore oil field in India, which accounts for around 25% of the country's oil production; Start up of new Azeri Central East (ACE) platform in Caspian Sea in 2Q24.
• Shareholder distributions: Dividend per ordinary share of 8 cents; $1.75 billion share buyback announced for 4Q24.

a) Divestment proceeds are disposal proceeds as per the condensed group cash flow statement. See page 3 for more information on other proceeds.

(b) Third quarter and full year 2024 include $0.3 billion to offset the expected dilution from the vesting of awards under employee share schemes (full year 2023 $0.7 billion).

(c) See Note 10 for more information.

RC profit (loss), underlying RC profit, net debt, ROACE, adjusted EBITDA, adjusted EBIDA, underlying RC profit per ordinary share and underlying RCprofit per ADS are non-IFRS measures. Inventory holding (gains) losses and adjusting items are non-IFRS adjustments.For structural cost reduction, see page 31 for more information.

* For items marked with an asterisk throughout this document, definitions are provided in the Glossary on page 34.

Highlights

4Q24 underlying replacement cost (RC) profit* $1.2 billion

• Underlying RC profit for the quarter was $1.2 billion, compared with $2.3 billion for the previous quarter. Compared with the third quarter 2024, the underlying result reflects weaker realized refining margins, higher impact from turnaround activity, seasonally lower customer volumes and fuels margins and higher other businesses & corporate underlying charge. The underlying effective tax rate (ETR)* in the quarter was 49%.
• Reported loss for the quarter was $2.0 billion, compared with a profit of $0.2 billion for the third quarter 2024. The reported result for the fourth quarter is adjusted for inventory holding losses* of $21 million (pre-tax) and a net adverse impact of adjusting items* of $3.4 billion (pre-tax) to derive the underlying RC profit. Adjusting items pre-tax include net impairments of $1.5 billion (see Note 4) and adverse fair value accounting effects* of $1.0 billion. See page 27 for more information on adjusting items.

Segment results

• Gas & low carbon energy: The RC profit before interest and tax for the fourth quarter 2024 was $1.8 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* for the fourth quarter was $2.0 billion, compared with $1.8 billion in the third quarter 2024. The fourth quarter underlying result before interest and tax is largely driven by higher realizations. The gas marketing and trading result was average.
• Oil production & operations: The RC profit before interest and tax for the fourth quarter 2024 was $2.6 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 $0.4 billion, the underlying RC profit before interest and tax for the fourth quarter was $2.9 billion, compared with $2.8 billion in the third quarter 2024. The fourth quarter underlying result before interest and tax reflects lower exploration write-offs, partly offset by lower realizations and volumes.
• Customers & products: The RC loss before interest and tax for the fourth quarter 2024 was $2.4 billion, compared with a profit of $23 million for the previous quarter. After adjusting RC loss before interest and tax for a net adverse impact of adjusting items of $2.1 billion, the underlying RC loss or profit before interest and tax (underlying result) for the fourth quarter was a loss of $0.3 billion, compared with a profit of $0.4 billion in the third quarter 2024. The customers fourth quarter underlying result was lower by $0.4 billion, reflecting lower fuels margins, seasonally lower volumes and adverse foreign exchange impacts. The products fourth quarter underlying result was lower by $0.3 billion, mainly reflecting weaker realized refining margins and a higher impact from turnaround activity. The oil trading contribution was weak.

Operating cash flow* $7.4 billion and net debt* $23.0 billion

• Operating cash flow of $7.4 billion, which includes a working capital* release of $1.3 billion (after adjusting for inventory holding losses, fair value accounting effects and other adjusting items), was around $0.7 billion higher than the previous quarter, reflecting lower cash taxes paid and timing of provision settlements, partly offset by lower underlying earnings. Net debt reduced to $23.0 billion compared to the third quarter, primarily driven by the impact of proceeds from divestments of around $2.8 billion, the issuance of perpetual hybrid bonds of $2.6 billion and acquired net debt of around $3.0 billion from the completion of the bp Bunge Bioenergia and Lightsource bp transactions.

Financial frame

• A resilient dividend is bp’s first priority within its disciplined financial frame, underpinned by a cash balance point* of around $40 per barrel Brent, $11 per barrel RMM and $3 per mmBtu Henry Hub (all 2021 real). For the fourth quarter, bp has announced a dividend per ordinary share of 8 cents.
• bp is committed to maintaining a strong balance sheet and strong investment grade credit rating. Through the cycle, we are targeting to further improve our credit metrics within an 'A' grade credit range.
• bp continues to invest with discipline and a returns focused approach in our transition growth* engines and in our oil, gas and refining businesses.
• The $1.75 billion share buyback programme announced with the third quarter results was completed on 7 February 2025. Related to the fourth quarter results, bp intends to execute a $1.75 billion share buyback prior to reporting the first quarter results. As part of our capital markets update scheduled for 26 February we intend to review elements of our financial guidance, including our expectations for 2025 share buybacks and capital expenditure*.
• In setting the dividend per ordinary share and buyback each quarter, the board will continue to take into account factors including the cumulative level of and outlook for surplus cash flow*, the cash balance point and maintaining a strong investment grade credit rating.

Further information

Contacts

bp press office, London: +44 20 7496 4076, bppress@bp.com

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 results 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’ 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 reserves; expectations regarding production and volumes; expectations regarding bp’s customers & products business; expectations regarding margins; expectations regarding underlying effective tax rate; expectations regarding turnaround and maintenance activity; expectations regarding financial performance, results of operations, finance debt acquired in the fourth quarter, and cash flows; expectations regarding cash cost savings delivery; expectations regarding future project start-ups; expectations regarding bp’s capital market update; expectations regarding shareholders returns; expectations regarding bp’s convenience businesses; bp’s financial guidance, including expectations for 2025 share buybacks and capital expenditure; bp’s plans and expectations regarding the amount and timing of share buybacks and dividends, including factors taken into account by the board; plans and expectations regarding bp’s credit rating, including in respect of maintaining a strong investment grade credit rating and targeting further improvements in credit metrics; plans and expectations regarding the allocation of surplus cash flow to share buybacks; plans and expectations regarding the sale of bp’s mobility and convenience and bp pulse business in Netherlands; plans and expectations regarding the sale of bp’s Ruhr Oel GmbH – BP Gelsenkirchen operation in Germany; plans and expectations regarding the sale of bp’s US onshore wind energy business; plans and expectations regarding development of hydrogen, bp’s electric vehicle (EV) charging infrastructure and RNG landfill plants; plans and expectations related to bp’s transition growth engines, including expected capital expenditures; plans and expectations regarding the amount or timing of payments related to divestment and other proceeds, and the timing, quantum and nature of certain acquisitions and divestments; expectations regarding the timing and amount of future payments relating to the Gulf of America oil spill; plans and expectations regarding bp’s guidance for 2025 and the first quarter of 2025, including expected production, growth, margins, businesses & corporate underlying annual charge, underlying ETR, timing and amount of divestment and other proceeds, depreciation, depletion and amortization; and plans and expectations regarding bp-operated projects, ventures, investments, joint ventures, partnerships and agreements with commercial entities and other third party partners, including but not limited to ADNOC, JERA Co., Inc, ONGC and the Republic of Iraq.
By their nature, forward-looking statements involve risk and uncertainty because they relate to events and depend on circumstances that will or may occur in the future and are outside the control of bp.
Actual results 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 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 2024 as filed with the US Securities and Exchange Commission (the “SEC”) as well as those factors discussed under “Risk factors” in bp’s Annual Report and Form 20-F for fiscal year 2023 as filed with the SEC.