The following Trading Statement provides a summary of BP p.l.c.’s (bp) current estimates and expectations for the second quarter of 2025, including data on the economic environment as well as group performance during the period.
The information presented is not comprehensive of all factors which may impact bp’s group results for the second quarter 2025 and is not an estimate of those results. Also refer to bp’s first quarter 2025 group results announcement on 29 April 2025 for second quarter and full year 2025 guidance items which continue to apply unless explicitly stated. A summary of that guidance is also provided in the Appendix to this Trading Statement. All information provided is subject to the finalization of bp’s financial reporting processes and actual results may vary.
bp’s group results for the second quarter 2025 are expected to be published on 5 August 2025.
Brent averaged $67.88/bbl in the second quarter 2025 compared to $75.73/bbl in the first quarter 2025.
US gas Henry Hub first of month index averaged $3.44/mmBtu in the second quarter 2025 compared to $3.65/mmBtu in the first quarter 2025.
The bp RMM* averaged $21.1/bbl in the second quarter 2025 compared to $15.2/bbl in the first quarter 2025.
WTI CMA* vs WCS, lagged 1 month averaged $10.01/bbl in the second quarter 2025 compared to $13.03/bbl in the first quarter 2025. Further information on prices and bp’s current rules of thumb can be found at the following link: bp.com Rules of Thumb
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. 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 (without limitation): price fluctuations in crude oil and natural gas; changes in demand for bp’s products; currency fluctuations; drilling and production results; reserves estimates; sales volume and sales mix numbers; supply and demand imbalances including as a result of direct or indirect restrictions on production; regional pricing differentials and refining margins; seasonal impacts on product demand and operating expenses; resolution of trading and derivative positions for the quarter; 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; 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 as well as those factors discussed under “Risk factors” in bp’s Annual Report and Form 20-F 2024 as filed with the US Securities and Exchange Commission. Furthermore, additional factors may exist that will be relevant to bp’s group results for the second quarter of 2025 that are not currently known or fully understood. Neither bp nor any of its subsidiaries assumes any obligation to update, revise or supplement any forward-looking statement contained in this announcement to reflect future circumstances, events or information.The contents of websites referred to in this announcement do not form part of this announcement.
Guidance Area |
Full Year 2025 |
2Q25 vs 1Q25 |
|---|---|---|
Reported and underlying* upstream production |
Reported upstream production to be lower and underlying upstream production to be slightly lower than 2024, of which oil production & operations broadly flat and gas & low carbon energy lower |
Reported upstream production to be broadly flat |
Customers |
Growth from convenience, including a full year contribution from bp bioenergy and a higher contribution from TravelCenters of America; earnings growth to be supported by structural cost reduction; fuels margins to remain sensitive to the cost of supply; earnings delivery to remain sensitive to the relative strength of the US dollar |
|
Products |
Broadly flat refining margins and stronger underlying performance underpinned by the absence of the plant-wide power outage at Whiting refinery; improvement plans across the portfolio; similar levels of turnaround activity, with phasing of turnaround activity in 2025 heavily weighted towards 1H25, with the highest impact in 2Q |
|
OB&C |
Around $1bn charge |
|
DD&A |
Broadly flat compared with 2024 |
|
Underlying effective tax rate*b |
Around 40% |
|
Capital expenditure* |
Around $14.5bn |
|
| Divestment and other proceeds | Around $3-4bn weighted towards 2H25 | |
| Gulf of America oil settlement payments | ~$1.2bn pre-tax, of which $1.1bn 2Q |
bp press office, London: bppress@bp.com
Investor relations: bp.com/investors
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.
Replacement cost (RC) profit or loss 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 a non-IFRS measure. The nearest equivalent measure on an IFRS basis is profit or loss attributable to bp shareholders.
The Refining marker margin (RMM) is the average of regional indicator margins weighted for bp’s crude refining capacity in each region. Each regional marker margin is based on product yields and a marker crude oil deemed appropriate for the region. The regional indicator margins may not be representative of the margins achieved by bp in any period because of bp’s particular refinery configurations and crude and product slate.
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.
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 before interest and tax for the operating segments or customers & products businesses is a non-IFRS measure and is calculated as RC profit or loss 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. The nearest equivalent measure on an IFRS basis for segments and businesses is RC profit or loss before interest and taxation.
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.
WTI CMA – The WCS differential to WTI calendar month average is based on a quoted Platts differential and used as a generic indicator. Actual crude differentials captured by bp’s refineries may vary significantly due to a variety of factors, such as apportionment, rationing or operational issues on third party crude logistics infrastructure.