EQS-Adhoc: BP p.l.c.: 4Q23 SEA Part 1 of 1

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“For a printer friendly version of this announcement please click on the link below to open a PDF version of the announcement”

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

2. See Note 9 for more information.

RC profit (loss), underlying RC profit (loss), surplus cash flow, net debt, ROACE, adjusted EBITDA, adjusted EBIDA, 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 34.

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Financial results

In addition to the highlights on page 2:

• Profit attributable to bp shareholders in the fourth quarter and full year was $0.4 billion and $15.2 billion respectively, compared with a profit of $10.8 billion and a loss of $2.5 billion in the same periods of 2022.

• After adjusting profit attributable to bp shareholders for inventory holding losses* and net impact of adjusting items*, underlying replacement cost profit* for the fourth quarter and full year was $3.0 billion and $13.8 billion respectively, compared with $4.8 billion and $27.7 billion for the same periods of 2022. This reduction in underlying replacement cost profit for the fourth quarter mainly reflects lower realizations and the impact of significantly lower refining margins, partially offset by a strong gas marketing and trading result. For the full year, the reduction reflects lower realizations, the impact of portfolio changes, the impact of lower refining margins and a lower oil trading performance.

• Adjusting items in the fourth quarter and full year had a net adverse pre-tax impact of $2.6 billion and a net favourable pre-tax impact of $1.1 billion respectively, compared with a favourable pre-tax impact of $9.7 billion and an adverse pre-tax impact of $29.8 billion in the same periods of 2022.

• Adjusting items for the fourth quarter and full year of 2023 include a favourable impact of pre-tax fair value accounting effects*, relative to management's internal measure of performance, of $2.6 billion and $9.4 billion respectively, compared with a favourable pre-tax impact of $13.2 billion and an adverse pre-tax impact of $3.5 billion in the same periods of 2022. This is primarily due to a decline in the forward price of LNG during 2023. Under IFRS, reported earnings include the mark-to-market value of the hedges used to risk-manage LNG contracts, but not of the LNG contracts themselves. The underlying result includes the mark-to-market value of the hedges but also recognizes changes in value of the LNG contracts being risk managed.

• Adjusting items for the fourth quarter and full year of 2023 also include net impairment charges (including impairment charges reported through equity-accounted earnings) of $4.6 billion and $7.0 billion, compared with net impairment charges of $3.8 billion and $18.6 billion in the same periods of 2022. The fourth quarter 2023 impairments have arisen largely as a result of changes in the group's price and discount rate assumptions, activity phasing, economic forecasts (in particular related to the Gelsenkirchen refinery) and portfolio composition. For further details on the impairment charges see Note 3.

• Adjusting items for the full year 2022 include a pre-tax charge of $24.0 billion relating to bp’s decision to exit its 19.75% shareholding in Rosneft. A further $1.5 billion pre-tax charge relating to bp's decision to exit its other businesses with Rosneft in Russia is also included.

• The effective tax rate (ETR) on RC profit or loss* for the fourth quarter and full year was 39% and 33% respectively, compared with 33% and 117% for the same periods in 2022. Excluding adjusting items, the underlying ETR* for the fourth quarter and full year was 42% and 39% respectively, compared with 40% and 34% for the same periods a year ago. The higher underlying ETR for the full year reflects changes in the geographical mix of profits and the increased impact of the UK Energy Profits Levy. ETR on RC profit or loss and underlying ETR are non-IFRS measures.

• Operating cash flow* for the fourth quarter and full year was $9.4 billion and $32.0 billion respectively, compared with $13.6 billion and $40.9 billion for the same periods in 2022 driven by the movements in underlying replacement cost profit and working capital in the periods.

• Capital expenditure* in the fourth quarter and full year was $4.7 billion and $16.3 billion respectively, compared with $7.4 billion and $16.3 billion in the same periods of 2022. The full year 2023 reflected the inorganic capital expenditure* of $1.1 billion for the acquisition of TravelCenters of America in the second quarter 2023. Full year 2022 included $3.0 billion in respect of the Archaea Energy acquisition.

• Total divestment and other proceeds for the fourth quarter and full year were $0.3 billion and $1.8 billion respectively, compared with $0.6 billion and $3.1 billion for the same periods in 2022. Other proceeds for full year 2023 were $0.5 billion of proceeds from the sale of a 49% interest in a controlled affiliate holding certain midstream assets onshore US. Other proceeds for full year 2022 were $0.6 billion of proceeds from the disposal of a loan note related to the Alaska divestment.

• At the end of the fourth quarter, net debt* was $20.9 billion, compared with $22.3 billion at the end of the third quarter 2023 and $21.4 billion at the end of the fourth quarter 2022.

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Analysis of RC profit (loss) before interest and tax and reconciliation to profit (loss) for the period

Analysis of underlying RC profit (loss) before interest and tax

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 6-14 for the segments.

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Operating Metrics

1. In 2023, bp acquired the US-based TravelCenters of America (TA) business. At the time of publication, TA reporting processes were still being integrated into bp’s reporting processes and as such, TA performance data is not included in reported data for 2023.

2. See Operational updates on pages 6, 9 and 11. Because of rounding, upstream production may not agree exactly with the sum of gas & low carbon energy and oil production & operations.

3. Mainly reflecting impact of portfolio changes.

Reserves replacement ratio*

The organic reserves replacement ratio on a combined basis of subsidiaries and equity-accounted entities was 47% for the year (2022 20%). The increase is largely due to additions in BPX Energy in the US and in the Middle East.

Outlook & Guidance

1Q24 guidance

• Looking ahead, bp expects first quarter 2024 reported upstream* production to be higher compared to fourth-quarter 2023.

• In its customers business, bp expects seasonally lower volumes across most businesses and the absence of one-off positive effects from the fourth quarter. In addition, bp expects fuels margins to remain sensitive to movements in cost of supply.

• In products, bp expects a significantly lower level of refinery turnaround activity compared to the fourth quarter. In addition, bp expects lower industry refining margins, with a larger reduction in realized margins due to narrower North American heavy crude oil differentials.

2024 guidance

In addition to the guidance on page 2:

• bp expects both reported and underlying upstream production* to be slightly higher compared with 2023. 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 expects continued growth from convenience, including a full year contribution from TravelCenters of America; a stronger contribution from Castrol underpinned by volume growth in focus markets; and continued margin growth from bp pulse driven by higher energy sold. In addition, bp expects fuels margins to remain sensitive to the cost of supply.

• In products, bp expects a lower level of industry refining margins, with realized margins impacted by narrower North American heavy crude oil differentials. bp expects refinery turnaround activity to have a similar impact on both throughput and financial performance compared to 2023, with phasing of activity in 2024 heavily weighted towards the second half.

• bp expects the other businesses & corporate underlying annual charge to be around $1.0 billion for 2024. The charge may vary from quarter to quarter.

• bp expects the depreciation, depletion and amortization to be slightly higher than 2023.

• bp expects the underlying ETR* for 2024 to be around 40% but it is sensitive to the impact that volatility in the current price environment may have on the geographical mix of the group’s profits and losses.

• bp expects capital expenditure* of around $16 billion, weighted to the first half.

• bp expects divestment and other proceeds of $2-3 billion in 2024, weighted towards the second half. Having realized $17.8 billion of divestment and other proceeds since the second quarter of 2020, bp continues to expect to reach $25 billion of divestment and other proceeds between the second half of 2020 and 2025.

• bp expects Gulf of Mexico oil spill payments for the year to be around $1.2 billion pre-tax including $1.1 billion pre-tax to be paid during the second quarter.

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gas & low carbon energy*

Financial results

• The replacement cost (RC) profit before interest and tax for the fourth quarter and full year was $2,169 million and $14,080 million respectively, compared with $16,439 million and $14,696 million for the same periods in 2022. The fourth quarter and full year are adjusted by a favourable impact of net adjusting items* of $392 million and $5,358 million respectively, compared with a favourable impact of net adjusting items of $13,291 million and an adverse impact of $1,367 million for the same periods in 2022. Adjusting items include impacts of fair value accounting effects*, relative to management's internal measure of performance, which are a favourable impact of $1,887 million and $8,859 million for the fourth quarter and full year in 2023 and a favourable impact of $12,502 million and an adverse impact of $1,811 million for the same periods in 2022. Under IFRS, reported earnings include the mark-to-market value of the hedges used to risk-manage LNG contracts, but not of the LNG contracts themselves. The underlying result includes the mark-to-market value of the hedges but also recognizes changes in value of the LNG contracts being risk managed. Adjusting items also include net impairment charges, see Note 3 for further information.

• After adjusting RC profit before interest and tax for adjusting items, the underlying RC profit before interest and tax* for the fourth quarter and full year was $1,777 million and $8,722 million respectively, compared with $3,148 million and $16,063 million for the same periods in 2022.

• The underlying RC profit for the fourth quarter, compared with the same period in 2022, reflects lower realizations and lower production, partially offset by a strong gas marketing and trading result. The underlying RC profit for the full year, compared with 2022, reflects lower realizations, and a higher depreciation, depletion and amortization charge.

Operational update

• Reported production for the quarter was 899mboe/d, 6.0% lower than the same period in 2022. Underlying production* was 3.8% lower, mainly due to base decline, particularly in Egypt, partly offset by major project* delivery.

• Reported production for the full year was 929mboe/d, 2.9% lower than the same period in 2022. Underlying production was 2.3% lower, mainly due to base decline, partly offset by major project delivery.

• Renewables pipeline* at the end of the quarter was 58.3GW (bp net), including 19.3GW bp net share of Lightsource bp's (LSbp's) pipeline. The renewables pipeline increased by 21.1GW net during the full year, including bp being awarded the rights to develop two North Sea offshore wind projects in Germany (4GW), increases to LSbp's pipeline (5.3GW), and an increase in dedicated hydrogen renewables (12.4GW). In addition, there is over 12GW (bp net) of early stage opportunities in LSbp's hopper.

Strategic progress

gas

• On 5 December, bp announced the restructuring of the ownership and commercial framework of the Atlantic LNG joint venture with its partners Shell and the National Gas Company of Trinidad & Tobago. The restructuring helps provide the certainty required for sanctioning the next wave of upstream gas projects and secures the long term LNG equity offtake for shareholders including bp.

• On 18 January the government of the Republic of Senegal approved bp’s exit from the Cayar Offshore Profond production sharing contract and designation of Kosmos Energy as the Operator of the Yakaar-Teranga gas resource.

• On 16 November, bp signed a 9-year sales and purchase agreement (SPA) with State-owned Oman LNG to buy one million metric tonnes per annum of LNG starting 2026.

low carbon energy

• During the quarter, we secured US Department of Energy funding confirmation for the MachH2 Hub hydrogen project in the US Midwest.

• On 25 January 2024 bp and Equinor announced they had signed an agreement under which they will restructure their investments in their US offshore wind projects. Subject to approvals, bp will assume full ownership of the Beacon projects and Equinor the Empire projects. bp will independently pursue future US offshore wind opportunities.

• On 30 November bp announced it has agreed to acquire the remaining 50.03% of Lightsource bp. LSbp is one of the world’s leading developers and operator of utility-scale solar and battery storage assets, with 1,200 employees in 19 countries. The acquisition includes LSbp’s hopper of 38GW renewables pipeline and an additional 25GW of early stage opportunities. The transaction is expected to close in the second half of 2024, subject to regulatory approvals.

• On 17 January 2024 bp announced it has agreed to acquire GETEC ENERGIE GmbH, a leading independent supplier of energy to commercial and industrial customers in Germany.

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gas & low carbon energy (continued)