6-K
Woodside Energy Group Ltd (WDS)
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 6-K
REPORT OF FOREIGN PRIVATE ISSUER
PURSUANT TO RULE 13a-16 OR 15d-16
UNDER THE SECURITIES EXCHANGE ACT OF 1934
For the month of April 2025
Commission File Number: 001-41404
Woodside Energy Group Ltd
(ABN 55 004 898 962)
(Registrant’s name)
Woodside Energy Group Ltd
Mia Yellagonga, 11 Mount Street
Perth, Western Australia 6000
Australia
(Address ofprincipal executive offices)
Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F.
Form 20-F ☑ Form 40-F ☐
Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(1): ☐
Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(7): ☐
EXHIBIT INDEX
| Exhibit No. | Description |
|---|---|
| 99.1 | A copy of the registrant’s Announcement, dated April 23, 2025, entitled “First Quarter 2025 Report”. |
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
Dated: April 23, 2025
| WOODSIDE ENERGY GROUP LTD | |
|---|---|
| By: | /s/ Damien Gare |
| Damien Gare<br> <br>Corporate Secretary |
EX-99.1
Exhibit 99.1
FIRST QUARTER REPORT FOR PERIOD ENDED 31 MARCH 2025
ASX: WDS | NYSE: WDS
Wednesday, 23 April 2025
Outstanding performance fromhigh quality assets
Operations
| • | Maintained exceptional production from Sangomar of 78 Mbbl/day (Woodside equity interest) produced in the quarter. |
|---|---|
| • | Quarterly production of 49.1 MMboe (546 Mboe/day), down 4% from Q4 2024 due to weather impacts at NWS and unplanned outages at Pluto, partially offset by higher production at Shenzi and Atlantis. Quarterly<br>production increased 9% from Q1 2024 due to the addition of Sangomar production. |
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| • | Quarterly revenue of $3,315 million, down 5% from Q4 2024 primarily due to lower production and lower oil-linked prices. Quarterly revenue increased 13% from Q1 2024<br>due to Sangomar start-up in July 2024 and high gas hub-linked prices. |
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| • | Sold 25.4% of produced LNG at prices linked to gas hub indices in the quarter (9.4% of total equity production). |
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Projects
| • | Strong project execution for the quarter, with all projects on schedule and budget. |
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| • | The Beaumont New Ammonia Project was 90% complete, with Phase 1 of the project on track for startup in the second half of 2025. |
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| • | The Scarborough Energy Project was 82% complete, and remains on track for first LNG cargo in the second half of 2026. |
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| • | The Trion Project was 26% complete, and remains on track for first oil in 2028. |
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Portfoliodevelopments
| • | Further streamlining Woodside’s portfolio and generating near-term cash flow by divesting the Greater Angostura assets.^1^ |
|---|---|
| • | Subsequent to the quarter, entered an agreement for the sale of a 40% interest in Louisiana LNG Infrastructure LLC.^2^ |
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| • | Subsequent to the quarter, signed LNG sale and purchase agreements with Uniper for the supply of up to two million tonnes per annum.^3^ |
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Woodside CEO Meg O’Neill said the company continued its focus on operational excellence and project delivery over the first quarter of 2025, while laying the foundation for Woodside’s next phase of value creation.
“We maintained world-class operational performance across our portfolio of high-quality assets, with Sangomar further boosting quarterly revenue through exceptional production of 78 thousand barrels per day at almost 98% reliability.
“Significant progress was made on our major growth projects, all of which are proceeding to schedule and within budget.
“At our Beaumont New Ammonia Project, pre-commissioning activities are expected to commence in the second quarter, with startup targeted for the second half of the year. This value-creating opportunity is set to deliver returns above our capital allocation framework and will position Woodside very competitively in the growing market for lower-carbon ammonia.
“Our Scarborough Energy Project is progressing as scheduled towards first LNG cargo in the second half of 2026, with the hull and topsides of the floating production unit being prepared for integration activities.
“The Trion Project is also gaining momentum. The construction of the subsea equipment and floating facilities is progressing well, and the project remains on schedule for first oil in 2028.
| ^1^ | Completion of the transaction is subject to conditions precedent. See “Woodside to divest Greater<br>Angostura assets to Perenco” announced 28 March 2025 for details. |
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| ^2^ | Completion of the transaction is subject to conditions precedent. See “Woodside announces Louisiana LNG<br>partnership with Stonepeak” announced 7 April 2025 for details. |
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| ^3^ | The sale and purchase agreements are subject to Woodside’s final investment decision on the three train<br>16.5 Mtpa foundation development of Louisiana LNG. See “Woodside signs LNG supply agreement with Uniper” announced on 17 April 2025 for details. |
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| 1 | First quarter report for period ended 31 March 2025 |
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“We are progressing at pace towards a final investment decision on Louisiana LNG, positioning Woodside as a global LNG powerhouse. We passed a major milestone on 7 April, announcing the sale of a 40% interest in the infrastructure entity to Stonepeak, a leading global investment firm. The accelerated capital contribution from Stonepeak enhances Louisiana LNG returns, reduces Woodside’s capital commitments and strengthens Woodside’s near-term capacity for shareholder distributions.
“The exceptional value proposition offered by Louisiana LNG was further demonstrated by our 17 April agreement for long-term supply of LNG to Uniper, whose leadership in European energy markets make it an ideal foundation customer for the project.
“We are pleased with the strong level of interest from potential strategic partners and are advancing discussions targeting further equity sell-down in Louisiana LNG.
“Louisiana LNG has a Foreign-Trade Zone, enabling the project to defer payment of tariffs until completion of each LNG train. We are assessing the potential impacts of recent tariff announcements and potential further trade measures on Louisiana LNG. Around 25% of Louisiana LNG’s estimated capital expenditure is equipment and materials, approximately half of which is currently expected to be sourced from the US.
“As Australia approaches a federal election, it is encouraging to see both major parties recognising the essential role of gas in supporting national prosperity and a stable energy transition. We look forward to certainty for ongoing operations at the North West Shelf beyond 2030, to enable it to support thousands of direct and indirect jobs, billions of dollars in taxes and royalties, and secure future gas supply to Western Australia.
“Customer demand for Woodside’s LNG remains robust. The 15-year sale and purchase agreement with China Resources announced during the quarter was Woodside’s fourth new long-term contract with a regional customer in just over a year.
“With significant growth in the pipeline, we continue to streamline our business to focus on core and high-value assets. Our agreement to divest the Greater Angostura assets in Trinidad and Tobago for $206 million underscores our disciplined approach to portfolio management and optimisation. We applied the same discipline in declining to progress Namibian Petroleum Exploration Licence 87, exiting H2TAS and reassessing the H2OK project.”
| 2 | First quarter report for period ended 31 March 2025 |
|---|
Comparative performance at a glance
| Q1<br><br><br>2025 | Q4<br><br><br>2024 | Change<br><br><br>% | Q1<br><br><br>2024 | Change<br><br><br>% | YTD<br><br><br>2025 | YTD<br><br><br>2024 | Change<br><br><br>% | ||
|---|---|---|---|---|---|---|---|---|---|
| Revenue^4^ | $ million | 3,315 | 3,484 | (5%) | 2,945 | 13% | 3,315 | 2,945 | 13% |
| Production^5^ | MMboe | 49.1 | 51.4 | (4%) | 44.9 | 9% | 49.1 | 44.9 | 9% |
| Gas | MMscf/d | 1,841 | 1,909 | (4%) | 1,929 | (5%) | 1,841 | 1,929 | (5%) |
| Liquids | Mbbl/d | 223 | 224 | —% | 155 | 44% | 223 | 155 | 44% |
| Total | Mboe/d | 546 | 559 | (2%) | 494 | 11% | 546 | 494 | 11% |
| Sales^6^ | MMboe | 50.2 | 54.1 | (7%) | 45.6 | 10% | 50.2 | 45.6 | 10% |
| Gas | MMscf/d | 1,962 | 2,129 | (8%) | 1,950 | 1% | 1,962 | 1,950 | 1% |
| Liquids | Mbbl/d | 213 | 214 | —% | 159 | 34% | 213 | 159 | 34% |
| Total | Mboe/d | 558 | 588 | (5%) | 501 | 11% | 558 | 501 | 11% |
| Average realisedprice | $/boe | 65 | 63 | 3% | 63 | 3% | 65 | 63 | 3% |
| Capital expenditure | $ million | 1,806 | 2,681 | (33%) | 1,158 | 56% | 1,806 | 1,158 | 56% |
| Capex excl. Louisiana LNG^7^ | $ million | 905 | 1,396 | (35%) | 1,158 | (22%) | 905 | 1,158 | (22%) |
| Louisiana LNG^8^ | $ million | 901 | 1,285 | (30%) | — | 100% | 901 | — | 100% |
Operations
Pluto LNG
| • | LNG reliability was 89.9% for the quarter due to the impact of three unplanned train outages, which were<br>rectified within days of each event. Facility performance continues to be proactively monitored to minimise the risk of future unplanned outages. |
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| • | Completed maintenance activities during facility downtime to minimise future planned outages.<br> |
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| • | Successfully processed additional volumes through the Pluto-KGP<br>Interconnector, using capacity at the North West Shelf. |
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North West Shelf (NWS) Project
| • | Achieved strong quarterly LNG reliability of 96.5%. |
|---|---|
| • | Received approvals from the North West Shelf Joint Venture for long lead items on the Greater Western<br>Flank Phase 4 Project, a five-well subsea tie-back to existing NWS offshore facilities. The project will support the delivery of domestic gas into the WA market during a forecasted shortfall in supply<br>post-2028, with a final investment decision (FID) planned for the second half of 2025. |
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| • | Successfully completed remote operations of offshore assets during a significant cyclone event, which<br>limited the impact on production. |
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| • | Continued LNG Train 2 permanent retirement activities following cessation of production in Q4 2024, with<br>retirement work scopes being undertaken in a phased manner. |
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Bass Strait
| • | Woodside approved investment in the Kipper 1B Project and the Turrum Phase 3 Project. Through the<br>development of these projects, Woodside is expected to add more than 100 petajoules (Woodside equity interest) to the south-eastern Australian domestic gas market, supplying local manufacturers, power generators, and homes. |
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| • | The Kipper 1B Project is expected to expand capacity from the Kipper field and deliver gas supplies ahead<br>of winter 2026 through the drilling of a subsea well and upgrades to the West Tuna platform. |
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| • | The Turrum Phase 3 Project is expected to deliver much-needed gas to south-eastern Australia by 2027 from<br>a five-well infill development of the Turrum and North Turrum fields and topsides modifications to the Marlin B platform. Once the project comes online, it will produce four times more gas than Queensland supplied to the southern states in 2024.<br> |
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| ^4^ | Restated to exclude periodic adjustments reflecting the arrangements governing Wheatstone LNG sales of<br>$14 million in Q4 2024 and -$24 million in Q1 2024. These amounts will be included within other income/(expenses) in the financial statements. Restatement allows for revenue presented in this quarterly report to reconcile to operating<br>revenue, the IFRS measure presented in Woodside Financial Statements. |
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| ^5^ | Q1 2025 includes 0.29 MMboe primarily from feed gas purchased from Pluto<br>non-operating participants processed through the Pluto-KGP Interconnector. |
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| ^6^ | Restated to exclude periodic adjustments reflecting the arrangements governing Wheatstone LNG sales of 0.22<br>MMboe in Q4 2024 and -0.28 MMboe in Q1 2024. Restatement allows for revenue presented in this quarterly report to reconcile to operating revenue, the IFRS measure presented in Woodside Financial Statements.<br> |
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| ^7^ | Includes capital additions on property plant and equipment, evaluation capitalised and other corporate spend.<br>Exploration capitalised has been reclassified from capital expenditure to other expenditure. |
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| ^8^ | Q4 2024 includes $1,066 million for purchase consideration of Louisiana LNG. Capital expenditure includes<br>100% working interest equity. |
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| 3 | First quarter report for period ended 31 March 2025 |
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Sangomar
| • | Achieved exceptional production of 99 thousand barrels per day (Mbbl/d) (100% basis, 78 Mbbl/d<br>Woodside share) at 97.6% reliability, with production from the Sangomar field remaining at plateau for the quarter. |
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| • | During the quarter, based on a positive response observed in S400 oil producers from water injection,<br>contingent resources were migrated to developed reserves. The reserve addition was 7.1 million barrels to proved (1P) reserves and 16.1 million barrels to proved plus probable (2P) reserves, Woodside share.^9^ As a result, Woodside expects Sangomar’s depreciation, depletion and amortisation (DD&A) rate for 2025 to decrease by 5 to 10% from its 2024 DD&A rate of approximately $56/boe.<br> |
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| • | Cargoes were delivered to China, Europe, US and Senegal’s domestic refinery. |
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United States of America
| • | Achieved outstanding reliability of 99.8% at Shenzi. |
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| • | Strong quarterly production at Shenzi was supported by a well returning to production in late 2024 and<br>ongoing optimisation efforts. |
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| • | Completed planned well intervention campaigns at Atlantis and commenced execution of an infill sidetrack<br>producer. |
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| • | Strong quarterly production from the Mad Dog field, Argos facility, with uplift seen from riser gas lift.<br> |
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Marketing
| • | Subsequent to the quarter, Woodside signed LNG sale and purchase agreements with Uniper for the supply of<br>1.0 million tonnes per annum (Mtpa) from Louisiana LNG LLC for up to 13 years from the commercial operations date (COD) of Louisiana LNG and up to 1.0 Mtpa from its global portfolio commencing with Louisiana LNG’s COD over a term until<br>2039.^10^ |
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| • | Signed a long-term sale and purchase agreement with China Resources Gas International Limited for supply<br>of approximately 0.6 million tonnes of LNG per year over 15 years on a delivered basis, commencing in 2027. |
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| • | Supplied 25.4% of produced LNG at prices linked to gas hub indices, realising a 23% premium<br>compared to oil-linked pricing. This represents 9.4% of Woodside’s total equity production. Full-year guidance remains unchanged at 28-35% of produced LNG.<br> |
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| • | Executed incremental Western Australian gas sales of 3.6 PJ for delivery in 2025 and 2026. Woodside<br>continues to engage with the Western Australian domestic market on additional supply requirements for 2025, 2026 and 2027. |
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| • | Delivered 526 TJ of trucked LNG, equivalent to 513 trailers, to customers in northern Western<br>Australia. |
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| • | Progressed preparations to release an expression of interest before 30 April 2025 for<br>Australia east coast natural gas supply to ensure compliance with the terms of Woodside’s Conditional Ministerial Exemption under the Gas Market Code.<br> |
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| ^9^ | Refer to Notes to petroleum reserves and resources on page 21 for details of disclaimers.<br> |
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| ^10^ | Completion of the transaction is subject to conditions precedent including final investment decision for the<br>Louisiana LNG development. See “Woodside announces Louisiana LNG partnership with Stonepeak” announced 7 April 2025 for details. |
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| 4 | First quarter report for period ended 31 March 2025 |
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Projects
Beaumont New Ammonia
| • | Progress continued with Train 1 construction 90% complete at the end of the quarter and onsite<br>workforce reaching peak numbers. Train 1 of the project remains on track to achieve first production in the second half of 2025, with pre-commissioning activities anticipated to begin in Q2 2025.^11^ |
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| • | Commenced electrical subsystem completion, with the site expected to switch from temporary to<br>permanent power in Q2 2025. |
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Scarborough Energy Project
| • | The Scarborough and Pluto Train 2 Project was 82% complete at the end of the quarter (excluding<br>Pluto Train 1 modifications). |
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| • | The floating production unit (FPU) hull exited its second dry dock, and the topsides were loaded<br>onto a transport barge in readiness for integration activities. |
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| • | Installation of the subsea production risers commenced.<br>Pre-installation of the FPU mooring chains was completed. Batch drilling of the intermediate sections of the development wells concluded. |
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| • | Activities at the Pluto Train 2 site are focused on piping and cable installation and preparing for<br>pre-commissioning activities. |
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| • | Site works for Pluto Train 1 modifications continue and construction activity at the module yard<br>ramped up. |
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| • | In February 2025, the Scarborough Offshore Facility and Trunkline (Operations) Environment Plan was<br>accepted by the regulator. |
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| • | First LNG cargo is targeted for the second half of 2026. |
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Trion
| • | The Trion Project was 26% complete at the end of the quarter. |
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| • | Completed the first steel cut for the three FPU topside modules in Korea and the floating storage<br>and offloading facility (FSO) disconnectable turret mooring system in China. Fabrication progressed on schedule, including the manufacturing of subsea equipment. |
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| • | Awarded the Operations and Maintenance contract for the FSO lease vessel. |
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| • | An Environmental Permit application has been submitted to the regulator, and progress is being made<br>on the submission of the HSE management system permit application. |
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Louisiana LNG
| • | Continued project scope under a limited notice to proceed with Bechtel. Site works include dry<br>excavation, clearing, area drainage improvements, mud mat installation, sheet piling and concrete work. |
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| • | All high value orders and major purchase orders (equipment and bulk materials) for train 1 and 2<br>have been released. Purchase orders for train 3 have also been placed. |
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| • | Subsequent to the quarter, Woodside entered into an agreement with Stonepeak for the sale of a 40%<br>equity interest in Louisiana LNG Infrastructure LLC. Under this transaction, Stonepeak has agreed to provide $5.7 billion towards the foundation development of Louisiana LNG on an accelerated basis, contributing 75% of the project capital<br>expenditure in both 2025 and 2026.^12^ |
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| • | Woodside continues to work towards FID readiness on the three train foundation development.<br> |
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Hydrogen Refueller @H2Perth^13^
| • | Commenced construction work on the project with ready for startup targeted for Q4 2025.<br> |
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| ^11^ | Phase 1 handover from OCI to Woodside remains subject to cost, schedule, and performance guarantees from OCI.<br>With limited exceptions, such as changes requested by Woodside, OCI will expend the resources necessary to complete the project ensuring that it meets the agreed performance standards prior to hand over. OCI will also be responsible for limited<br>financial payments to Woodside if the project is delayed beyond September 2025. |
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| ^12^ | Completion of the transaction is subject to conditions precedent. See “Woodside announces Louisiana LNG<br>partnership with Stonepeak” announced 7 April 2025 for details. |
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| ^13^ | The project has received funding from the Hydrogen Fuelled Transport Project Funding Process as part of the<br>Western Australian Government’s Renewable Hydrogen Strategy. |
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| 5 | First quarter report for period ended 31 March 2025 |
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Decommissioning
| • | Safely and successfully completed the removal of all facilities from Enfield, offshore Western<br>Australia, with the recovery of final infrastructure in February. With only survey activities remaining, this concludes the multi-year decommissioning program at Enfield. |
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| • | Subsequent to the quarter, Woodside concluded the ten-well<br>Stybarrow plug and abandonment campaign. |
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| • | Subsequent to the quarter, a mobile offshore drilling unit arrived at the Minerva field, offshore<br>Victoria, and commenced preparations to plug and abandon the first of three Minerva wells. |
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| • | Commenced deconstruction of the Griffin Riser Turret Mooring at the Australian Marine Complex in<br>preparation for recycling and reuse. |
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| • | Continued decommissioning activities at Bass Strait, completing the plug and abandonment activities<br>for 27 wells, including on the Bream B platform. Plug and abandonment activities commenced on the Kingfish A and Cobia platforms. |
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Exploration and development
Browse
| • | Work continued on the Browse to North West Shelf Project to optimise the development concept,<br>advance key regulatory approvals and progress commercial discussions to process Browse volumes through the Karratha Gas Plant. |
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Calypso
| • | Progressed<br>pre-front-end engineering design (FEED) engineering studies and subsurface studies to mature the technical and commercial definition of the development concept.<br> |
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Exploration
| • | Woodside declined to exercise the option to acquire at least a 56% interest in the Namibian<br>Petroleum Exploration Licence 87. |
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New energy and carbon solutions
New energy
| • | With the acquisition of Beaumont New Ammonia, plans for Woodside’s H2OK project are being reassessed.<br>Subsequent to the quarter, exit from the H2TAS project was formalised. |
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| • | Commitment to existing climate targets remain firm with these decisions following a review of<br>global new energy opportunities to ensure there is alignment between Woodside’s corporate strategy, capital allocation framework, business priorities and external market conditions.^14^<br> |
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Carbon capture and storage (CCS) opportunities
| • | Angel CCS completed engineering studies as part of pre-FEED<br>and commenced engagement with potential customers for CCS services. |
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Corporate activities
Greater Angostura assets divestment
| • | Woodside entered into an agreement in March 2025 with Perenco to divest its Greater Angostura<br>assets in Trinidad and Tobago for $206 million. The divestment is inclusive of Woodside’s interest in the shallow water Angostura and Ruby offshore oil and gas fields, associated production facilities and onshore terminal. The transaction<br>provides near-term cash flow to support ongoing investments and shareholder distributions and builds on the Australian asset swap announced in December 2024, further streamlining Woodside’s portfolio.^15^ The transaction is expected to close in Q3 2025, with an effective date of 1 January 2025. Completion of the transaction is subject to conditions precedent.<br> |
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| ^14^ | Refer to the Climate section within the Annual Report 2024 for further details on Woodside’s climate<br>targets. |
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| ^15^ | See “Woodside simplifies portfolio and unlocks long-term value” announced 19 December 2024 for<br>details concerning the Australian asset swap. Completion of the transaction is expected to occur in 2026. |
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| 6 | First quarter report for period ended 31 March 2025 |
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Climate and sustainability
| • | Woodside held a Sustainability Briefing on 3 April 2025, part of a structured program of<br>engagement with investors on the company’s approach to climate and other sustainability topics. The briefing was held following the release of Woodside’s Sustainability disclosures in February 2025. |
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| • | Woodside awarded a A$35 million contract to Cherratta Lodge, a Traditional Owner operated<br>business in Karratha, Western Australia, for provision of accommodation to the workforce for Pluto Train 1 modifications. This is the first time Woodside has awarded a village accommodation contract to a Traditional Owner business and is part of the<br>significant local economic benefits arising from the project. |
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Hedging
| • | Of the 30 MMboe of 2025 oil production previously hedged at an average price of approximately $78.7<br>per barrel, approximately 25% was delivered by the end of the quarter. |
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| • | Woodside also has a hedging program for Corpus Christi LNG volumes designed to protect against<br>downside pricing risk. These hedges are Henry Hub (HH) and Title Transfer Facility (TTF) commodity swaps. Approximately 95% of 2025 and 87% of 2026 volumes have been hedged. |
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| • | The realised value of all hedged positions for the quarter ended 31 March 2025 is a pre-tax profit of approximately $14 million, with a $32 million profit related to oil price hedges offset by a $23 million loss related to Corpus Christi hedges, and a $5 million profit related<br>to other hedge positions. Hedging profit will be included in “other income” in the full-year financial statements. |
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Fundingand liquidity
| • | In the quarter, Woodside: |
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| • | Entered into two $1,500 million short term liquidity facilities. |
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| • | Repaid a $1,000 million bond that matured during the quarter. |
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| • | Drew $800 million from available liquidity debt facilities. |
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| • | Following the payment of the 2024 final dividend on 2 April 2025, Woodside had liquidity of<br>$7,300 million. |
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Embedded commodity derivative
| • | In 2023, Woodside entered into a revised long-term gas sale and purchase contract with Perdaman. The contract was<br>assessed to contain an embedded commodity derivative, where a component of the selling price is linked to the price of urea. For the quarter ended 31 March 2025, an unrealised gain of $17 million has been recognised through other income.<br>The fair value of the Perdaman embedded derivative has been estimated using a Monte Carlo simulation model. The valuation approach is currently under review for improvement opportunities. |
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Annual General Meeting
| • | Woodside’s hybrid meeting will be held on Thursday, 8 May 2025 at 10.00am (AWST) online<br>and at the Crown Ballroom at Crown Towers, Burswood, Western Australia. Shareholders and their proxyholders are welcome to participate online at<br>meetings.lumiconnect.com/300-261-170-058 or in person. Further details of Woodside’s meeting arrangements (including<br>security measures) are available at woodside.com/investors. |
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Upcoming events 2025
| May | 8 | Annual General Meeting |
|---|---|---|
| July | 23 | Second quarter 2025 report |
| August | 19 | Half-Year 2025 report |
| October | 22 | Third quarter 2025 report |
| 7 | First quarter report for period ended 31 March 2025 | |
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2025 full-year guidance
| Prior | Current | ||
|---|---|---|---|
| Production | MMboe | 186 - 196 | No change |
| Gas hubexposure^16^ | % of produced LNG | 28 - 35 | No change |
| Unitproduction cost | $/boe | 8.5 - 9.2 | No change |
| Property, plant andequipment<br> <br>depreciation and amortisation | $ million | 4,500 - 5,000 | No change |
| Explorationexpense | $ million | 200 | No change |
| Payments forrestoration | $ million | 700 - 1,000 | No change |
| Capitalexpenditure^17^ | $ million | 4,500 - 5,000 | No change |
| Contacts: | |||
| --- | --- | --- | |
| INVESTORS | MEDIA | REGISTERED ADDRESS | |
| Woodside Energy Group Ltd | |||
| ACN 004 898 962 | |||
| Sarah Peyman | Christine Forster | Mia Yellagonga | |
| M: +61 457 513 249 | M: +61 484 112 469 | 11 Mount Street | |
| E: [email protected] | E: [email protected] | Perth WA 6000 | |
| Australia | |||
| T: +61 8 9348 4000 | |||
| www.woodside.com |
This announcement was approved and authorised for release by Woodside’s Disclosure Committee.
| ^16^ | Gas hub indices include Japan Korea Marker (JKM), TTF and National Balancing Point (NBP). It excludes HH.<br> |
|---|---|
| ^17^ | Capital expenditure includes the following participating interests; Sangomar (82%); Scarborough (74.9%), Pluto<br>Train 2 (51%), Trion (60%) and working interest equity prior to the completion of the asset swap with Chevron for NWS Project, NWS Oil Project, Wheatstone, Julimar-Brunello and Angel CCS assets. It includes the remaining Beaumont New Ammonia<br>acquisition expenditure. This guidance assumes no change to these participating interests in 2025. This excludes the impact of any subsequent asset sell-downs, future acquisitions or other changes in equity. It excludes Louisiana LNG expenditure.<br> |
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| 8 | First quarter report for period ended 31 March 2025 |
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Production summary
| Q1<br><br><br>2025 | Q4<br><br><br>2024 | Q1<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | |||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Gas | MMscf/d | 1,841 | 1,909 | 1,929 | 1,841 | 1,929 | |||||
| Liquids | Mbbl/d | 223 | 224 | 155 | 223 | 155 | |||||
| Total | Mboe/d | **** | 546 | **** | 559 | **** | 494 | **** | 546 | **** | 494 |
| Q1<br><br><br>2025 | Q4<br><br><br>2024 | Q1<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | |||||||
| AUSTRALIA | |||||||||||
| LNG | |||||||||||
| North West Shelf | Mboe | 6,395 | 7,117 | 8,192 | 6,395 | 8,192 | |||||
| Pluto^18^ | Mboe | 10,430 | 11,232 | 11,754 | 10,430 | 11,754 | |||||
| Wheatstone | Mboe | 2,422 | 2,460 | 2,357 | 2,422 | 2,357 | |||||
| Total | Mboe | 19,247 | 20,809 | 22,303 | 19,247 | 22,303 | |||||
| Pipeline gas | |||||||||||
| Bass Strait | Mboe | 3,192 | 3,140 | 2,359 | 3,192 | 2,359 | |||||
| Other^19^ | Mboe | 3,807 | 4,136 | 3,278 | 3,807 | 3,278 | |||||
| Total | Mboe | 6,999 | 7,276 | 5,637 | 6,999 | 5,637 | |||||
| Crude oil and condensate | |||||||||||
| North West Shelf | Mbbl | 1,106 | 1,250 | 1,412 | 1,106 | 1,412 | |||||
| Pluto^18^ | Mbbl | 857 | 911 | 931 | 857 | 931 | |||||
| Wheatstone | Mbbl | 441 | 423 | 462 | 441 | 462 | |||||
| Bass Strait | Mbbl | 402 | 482 | 492 | 402 | 492 | |||||
| Macedon & Pyrenees | Mbbl | 369 | 617 | 109 | 369 | 109 | |||||
| Ngujima-Yin | Mbbl | 725 | 1,143 | 886 | 725 | 886 | |||||
| Okha | Mbbl | 312 | 616 | 466 | 312 | 466 | |||||
| Total | Mboe | 4,212 | 5,442 | 4,758 | 4,212 | 4,758 | |||||
| NGL | |||||||||||
| North West Shelf | Mbbl | 230 | 274 | 290 | 230 | 290 | |||||
| Pluto^18^ | Mbbl | 52 | 58 | 54 | 52 | 54 | |||||
| Bass Strait | Mbbl | 668 | 740 | 832 | 668 | 832 | |||||
| Total | Mboe | 950 | 1,072 | 1,176 | 950 | 1,176 | |||||
| Total Australia^20^ | Mboe | **** | 31,408 | **** | 34,599 | **** | 33,874 | **** | 31,408 | **** | 33,874 |
| Mboe/d | **** | 349 | **** | 376 | **** | 372 | **** | 349 | **** | 372 | |
| ^18^ | Q1 2025 includes 2.04 MMboe of LNG, 0.10 MMboe of condensate and 0.05 MMboe of NGL processed at the Karratha<br>Gas Plant (KGP) through the Pluto-KGP Interconnector. | ||||||||||
| --- | --- | ||||||||||
| ^19^ | Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.<br> | ||||||||||
| --- | --- | ||||||||||
| ^20^ | Q1 2025 includes 0.29 MMboe primarily from feed gas purchased from Pluto<br>non-operating participants processed through the Pluto-KGP Interconnector. | ||||||||||
| --- | --- | ||||||||||
| 9 | First quarter report for period ended 31 March 2025 | ||||||||||
| --- | --- | ||||||||||
| Q1<br><br><br>2025 | Q4<br><br><br>2024 | Q1<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | |||||||
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| INTERNATIONAL | |||||||||||
| Pipeline gas | |||||||||||
| USA | Mboe | 378 | 305 | 360 | 378 | 360 | |||||
| Trinidad & Tobago | Mboe | 2,416 | 2,425 | 2,503 | 2,416 | 2,503 | |||||
| Other^21^ | Mboe | 23 | - | - | 23 | - | |||||
| Total | Mboe | 2,817 | 2,730 | 2,863 | 2,817 | 2,863 | |||||
| Crude oil and condensate | |||||||||||
| Atlantis | Mbbl | 2,472 | 2,238 | 2,441 | 2,472 | 2,441 | |||||
| Mad Dog | Mbbl | 2,577 | 2,607 | 2,765 | 2,577 | 2,765 | |||||
| Shenzi | Mbbl | 2,322 | 1,832 | 2,405 | 2,322 | 2,405 | |||||
| Trinidad & Tobago | Mbbl | 99 | 140 | 126 | 99 | 126 | |||||
| Sangomar | Mbbl | 7,010 | 6,901 | - | 7,010 | - | |||||
| Other^21^ | Mbbl | - | 81 | 81 | - | 81 | |||||
| Total | Mboe | 14,480 | 13,799 | 7,818 | 14,480 | 7,818 | |||||
| NGL | |||||||||||
| USA | Mbbl | 398 | 320 | 393 | 398 | 393 | |||||
| Other^21^ | Mbbl | 12 | - | - | 12 | - | |||||
| Total | Mboe | 410 | 320 | 393 | 410 | 393 | |||||
| Total International | Mboe | **** | 17,707 | **** | 16,849 | **** | 11,074 | **** | 17,707 | **** | 11,074 |
| Mboe/d | **** | 197 | **** | 183 | **** | 122 | **** | 197 | **** | 122 | |
| Total Production | Mboe | **** | 49,115 | **** | 51,448 | **** | 44,948 | **** | 49,115 | **** | 44,948 |
| Mboe/d | **** | 546 | **** | 559 | **** | 494 | **** | 546 | **** | 494 | |
| ^21^ | Overriding royalty interests held in the USA for several producing wells. | ||||||||||
| --- | --- | ||||||||||
| 10 | First quarter report for period ended 31 March 2025 | ||||||||||
| --- | --- |
Product sales
| Q1<br><br><br>2025 | Q4<br><br><br>2024 | Q1<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | |||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Gas | MMscf/d | 1,962 | 2,129 | 1,950 | 1,962 | 1,950 | |||||
| Liquids | Mbbl/d | 213 | 214 | 159 | 213 | 159 | |||||
| Total | Mboe/d | **** | 558 | **** | 588 | **** | 501 | **** | 558 | **** | 501 |
| Q1<br><br><br>2025 | Q4<br><br><br>2024 | Q1<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | |||||||
| AUSTRALIA | |||||||||||
| LNG | |||||||||||
| North West Shelf | Mboe | 6,887 | 6,753 | 8,008 | 6,887 | 8,008 | |||||
| Pluto | Mboe | 9,676 | 10,490 | 10,513 | 9,676 | 10,513 | |||||
| Wheatstone^22^ | Mboe | 2,217 | 2,503 | 2,308 | 2,217 | 2,308 | |||||
| Total | Mboe | 18,780 | 19,746 | 20,829 | 18,780 | 20,829 | |||||
| Pipeline gas | |||||||||||
| Bass Strait | Mboe | 3,299 | 3,320 | 2,570 | 3,299 | 2,570 | |||||
| Other^23^ | Mboe | 3,584 | 4,058 | 2,894 | 3,584 | 2,894 | |||||
| Total | Mboe | 6,883 | 7,378 | 5,464 | 6,883 | 5,464 | |||||
| Crude oil and condensate | |||||||||||
| North West Shelf | Mbbl | 1,229 | 1,203 | 1,214 | 1,229 | 1,214 | |||||
| Pluto | Mbbl | 705 | 1,093 | 640 | 705 | 640 | |||||
| Wheatstone | Mbbl | 334 | 319 | 329 | 334 | 329 | |||||
| Bass Strait | Mbbl | 534 | 518 | 597 | 534 | 597 | |||||
| Ngujima-Yin | Mbbl | 663 | 1,006 | 999 | 663 | 999 | |||||
| Okha | Mbbl | - | 653 | 618 | - | 618 | |||||
| Macedon & Pyrenees | Mbbl | 499 | 472 | 496 | 499 | 496 | |||||
| Total | Mboe | 3,964 | 5,264 | 4,893 | 3,964 | 4,893 | |||||
| NGL | |||||||||||
| North West Shelf | Mbbl | 477 | 252 | 255 | 477 | 255 | |||||
| Pluto | Mbbl | 110 | 53 | 55 | 110 | 55 | |||||
| Bass Strait | Mbbl | 226 | 303 | 785 | 226 | 785 | |||||
| Total | Mboe | 813 | 608 | 1,095 | 813 | 1,095 | |||||
| Total Australia | Mboe | **** | 30,440 | **** | 32,996 | **** | 32,281 | **** | 30,440 | **** | 32,281 |
| Mboe/d | **** | 338 | **** | 359 | **** | 355 | **** | 338 | **** | 355 | |
| ^22^ | Restated to exclude periodic adjustments reflecting the arrangements governing Wheatstone LNG sales of 0.22<br>MMboe in Q4 2024 and -0.28 MMboe in Q1 2024. Restatement allows for revenue presented in this quarterly report to reconcile to operating revenue, the IFRS measure presented in Woodside Financial Statements.<br> | ||||||||||
| --- | --- | ||||||||||
| ^23^ | Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.<br> | ||||||||||
| --- | --- | ||||||||||
| 11 | First quarter report for period ended 31 March 2025 | ||||||||||
| --- | --- | ||||||||||
| Q1<br><br><br>2025 | Q4<br><br><br>2024 | Q1<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | |||||||
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| INTERNATIONAL | |||||||||||
| Pipeline gas | |||||||||||
| USA | Mboe | 294 | 231 | 286 | 294 | 286 | |||||
| Trinidad & Tobago | Mboe | 2,274 | 2,802 | 2,457 | 2,274 | 2,457 | |||||
| Other^24^ | Mboe | 4 | 6 | 6 | 4 | 6 | |||||
| Total | Mboe | 2,572 | 3,039 | 2,749 | 2,572 | 2,749 | |||||
| Crude oil and condensate | |||||||||||
| Atlantis | Mbbl | 2,494 | 2,108 | 2,426 | 2,494 | 2,426 | |||||
| Mad Dog | Mbbl | 2,620 | 2,629 | 2,626 | 2,620 | 2,626 | |||||
| Shenzi | Mbbl | 2,202 | 1,730 | 2,352 | 2,202 | 2,352 | |||||
| Trinidad & Tobago | Mbbl | 43 | 53 | 52 | 43 | 52 | |||||
| Sangomar | Mbbl | 6,521 | 6,793 | - | 6,521 | - | |||||
| Other^24^ | Mbbl | 57 | 42 | 60 | 57 | 60 | |||||
| Total | Mboe | 13,937 | 13,355 | 7,516 | 13,937 | 7,516 | |||||
| NGL | |||||||||||
| USA | Mbbl | 371 | 303 | 413 | 371 | 413 | |||||
| Other^24^ | Mbbl | 2 | 4 | 3 | 2 | 3 | |||||
| Total | Mboe | 373 | 307 | 416 | 373 | 416 | |||||
| Total International | Mboe | **** | 16,882 | **** | 16,701 | **** | 10,681 | **** | 16,882 | **** | 10,681 |
| Mboe/d | **** | 188 | **** | 182 | **** | 117 | **** | 188 | **** | 117 | |
| MARKETING^25^ | |||||||||||
| LNG | Mboe | 2,750 | 4,196 | 2,086 | 2,750 | 2,086 | |||||
| Liquids | Mboe | 104 | 160 | 571 | 104 | 571 | |||||
| Total | Mboe | 2,854 | 4,356 | 2,657 | 2,854 | 2,657 | |||||
| Total Marketing | Mboe | **** | 2,854 | **** | 4,356 | **** | 2,657 | **** | 2,854 | **** | 2,657 |
| Total sales | Mboe | **** | 50,176 | **** | 54,053 | **** | 45,619 | **** | 50,176 | **** | 45,619 |
| Mboe/d | **** | 558 | **** | 588 | **** | 501 | **** | 558 | **** | 501 | |
| ^24^ | Overriding royalty interests held in the USA for several producing wells. | ||||||||||
| --- | --- | ||||||||||
| ^25^ | Purchased volumes sourced from third parties. | ||||||||||
| --- | --- | ||||||||||
| 12 | First quarter report for period ended 31 March 2025 | ||||||||||
| --- | --- |
Revenue (US$ million)
| Q1<br><br><br>2025 | Q4<br><br><br>2024 | Q1<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | ||||||
|---|---|---|---|---|---|---|---|---|---|---|
| AUSTRALIA | ||||||||||
| North West Shelf | 535 | 497 | 592 | 535 | 592 | |||||
| Pluto | 712 | 853 | 745 | 712 | 745 | |||||
| Wheatstone^26^ | 199 | 213 | 199 | 199 | 199 | |||||
| Bass Strait | 228 | 217 | 223 | 228 | 223 | |||||
| Macedon | 52 | 49 | 51 | 52 | 51 | |||||
| Ngujima-Yin | 57 | 84 | 92 | 57 | 92 | |||||
| Okha | - | 50 | 50 | - | 50 | |||||
| Pyrenees | 44 | 40 | 44 | 44 | 44 | |||||
| TotalAustralia | **** | 1,827 | **** | 2,003 | **** | 1,996 | **** | 1,827 | **** | 1,996 |
| INTERNATIONAL | ||||||||||
| Atlantis | 191 | 156 | 196 | 191 | 196 | |||||
| Mad Dog | 190 | 183 | 204 | 190 | 204 | |||||
| Shenzi | 167 | 124 | 190 | 167 | 190 | |||||
| Trinidad & Tobago^27^ | 66 | 66 | 61 | 66 | 61 | |||||
| Sangomar | 481 | 484 | - | 481 | - | |||||
| Other^28^ | 3 | 2 | 5 | 3 | 5 | |||||
| TotalInternational | **** | 1,098 | **** | 1,015 | **** | 656 | **** | 1,098 | **** | 656 |
| Marketingrevenue^29^ | 312 | 410 | 227 | 312 | 227 | |||||
| Total salesrevenue^30^ | 3,237 | 3,428 | 2,879 | 3,237 | 2,879 | |||||
| Processing revenue | 74 | 53 | 61 | 74 | 61 | |||||
| Shipping and other<br>revenue | 4 | 3 | 5 | 4 | 5 | |||||
| Totalrevenue | **** | 3,315 | **** | 3,484 | **** | 2,945 | **** | 3,315 | **** | 2,945 |
| ^26^ | Restated to exclude periodic adjustments reflecting the arrangements governing Wheatstone LNG sales of<br>$14 million in Q4 2024 and -$24 million in Q1 2024. These amounts will be included within other income/(expenses) in the financial statements. Restatement allows for revenue presented in this quarterly report to reconcile to operating<br>revenue, the IFRS measure presented in Woodside Financial Statements. | |||||||||
| --- | --- | |||||||||
| ^27^ | Includes the impact of periodic adjustments related to the production sharing contract (PSC).<br> | |||||||||
| --- | --- | |||||||||
| ^28^ | Overriding royalty interests held in the USA for several producing wells. | |||||||||
| --- | --- | |||||||||
| ^29^ | Values include revenue generated from purchased LNG and Liquids volumes, as well as the marketing margin on the<br>sale of Woodside’s produced LNG and Liquids portfolio. Marketing revenue excludes hedging impacts and cargo swaps where a Woodside produced cargo is sold and repurchased from the same counterparty to optimise the portfolio. The margin for these<br>cargo swaps is recognised net in other income. | |||||||||
| --- | --- | |||||||||
| ^30^ | Referred to as ‘Revenue from sale of hydrocarbons’ in Woodside financial statements. Total sales<br>revenue excludes all hedging impacts. | |||||||||
| --- | --- | |||||||||
| 13 | First quarter report for period ended 31 March 2025 | |||||||||
| --- | --- |
Realised prices
| Units | Q4<br><br><br>2024 | Q1<br><br><br>2024 | Units | Q4<br><br><br>2024 | Q1<br><br><br>2024 | |||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| LNG produced | /MMBtu | 10.6 | 10.8 | 10.4 | /boe | 67 | 69 | 67 | ||||
| LNG traded^31^ | /MMBtu | 13.7 | 12.6 | 9.1 | /boe | 86 | 80 | 59 | ||||
| Pipeline gas | /boe | 36 | 33 | 34 | ||||||||
| Oil and condensate | /bbl | 74 | 71 | 79 | /boe | 74 | 71 | 79 | ||||
| NGL | /bbl | 47 | 45 | 47 | /boe | 47 | 45 | 47 | ||||
| Liquids traded^31^ | /bbl | 70 | 67 | 60 | /boe | 70 | 67 | 60 | ||||
| Average realised price for pipeline gas: | ||||||||||||
| Western Australia | A/GJ | 6.9 | 6.6 | 6.4 | ||||||||
| East Coast Australia | A/GJ | 14.0 | 12.7 | 13.7 | ||||||||
| International | /Mcf | 5.0 | 4.2 | 4.6 | ||||||||
| Average realised price | /boe | 65 | 63 | 63 | ||||||||
| Dated Brent | /bbl | 76 | 75 | 83 | ||||||||
| JCC (lagged three months) | /bbl | 78 | 86 | 92 | ||||||||
| WTI | /bbl | 71 | 70 | 77 | ||||||||
| JKM | /MMBtu | 14.7 | 13.5 | 11.9 | ||||||||
| TTF | /MMBtu | 14.6 | 12.8 | 9.8 |
All values are in US Dollars.
Average realised price increased 3% from the prior quarter reflecting higher Dated Brent and WTI.
| ^31^ | Excludes any additional benefit attributed to produced volumes through third-party trading activities.<br> |
|---|---|
| 14 | First quarter report for period ended 31 March 2025 |
| --- | --- |
Capital expenditure (US$ million)
| Q4<br><br><br>2024 | Q1<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | ||||||
|---|---|---|---|---|---|---|---|---|---|
| Evaluation capitalised32 | 12 | 17 | 17 | 12 | 17 | ||||
| Property plant & equipment | 889 | 1,315 | 1,090 | 889 | 1,090 | ||||
| Other<br>33 | 4 | 64 | 51 | 4 | 51 | ||||
| Sub Total (excluding Louisiana<br>LNG) | 905 | **** | 1,396 | **** | 1,158 | **** | 905 | **** | 1,158 |
| Louisiana<br>LNG34 | 901 | 1,285 | - | 901 | - | ||||
| Total | 1,806 | **** | 2,681 | **** | 1,158 | **** | 1,806 | **** | 1,158 |
| Q4<br><br><br>2024 | Q1<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | ||||||
| Scarborough | 322 | 664 | 574 | 322 | 574 | ||||
| Trion | 315 | 299 | 97 | 315 | 97 | ||||
| Sangomar | 7 | 112 | 210 | 7 | 210 | ||||
| Other | 261 | 321 | 277 | 261 | 277 | ||||
| Sub Total (excluding<br>Louisiana LNG) | 905 | **** | 1,396 | **** | 1,158 | **** | 905 | **** | 1,158 |
| Louisiana<br>LNG34 | 901 | 1,285 | - | 901 | - | ||||
| Total | 1,806 | **** | 2,681 | **** | 1,158 | **** | 1,806 | **** | 1,158 |
| Other expenditure (US million) | |||||||||
| Q4<br><br><br>2024 | Q1<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | ||||||
| Exploration capitalised32,35 | 5 | - | 21 | 5 | 21 | ||||
| Exploration and evaluation<br>expensed36 | 35 | 140 | 54 | 35 | 54 | ||||
| Permit amortisation | 3 | 2 | 3 | 3 | 3 | ||||
| Total | 43 | **** | 142 | **** | 78 | **** | 43 | **** | 78 |
| Trading<br>costs | 232 | **** | 290 | **** | 145 | **** | 232 | **** | 145 |
All values are in US Dollars.
| ^32^ | Project final investment decisions result in amounts of previously capitalised exploration and evaluation<br>expense (from current and prior years) being transferred to property plant & equipment. This table does not reflect the impact of such transfers. |
|---|---|
| ^33^ | Other primarily incorporates corporate spend including SAP build costs, other investments and other capital<br>expenditure. |
| --- | --- |
| ^34^ | Q4 2024 includes $1,066 million for purchase consideration of Louisiana LNG. The purchase consideration is<br>the total amount paid for acquiring the companies encompassing all assets and liabilities as part of the transaction. Capital expenditure includes 100% working interest equity. |
| --- | --- |
| ^35^ | Exploration capitalised has been reclassified from capital expenditure to other expenditure. Exploration<br>capitalised represents expenditure on successful and pending wells, plus permit acquisition costs during the period and is net of well costs reclassified to expense on finalisation of well results. |
| --- | --- |
| ^36^ | Includes seismic and general permit activities and other exploration costs. |
| --- | --- |
| 15 | First quarter report for period ended 31 March 2025 |
| --- | --- |
Exploration or appraisal wells drilled
No exploration or appraisal wells were drilled in the quarter.
Permits and licences
Key changes to permit and licence holdings during the quarter ended 31 March 2025 are noted below.
| Region | Permits or licence<br><br><br>areas | Change in interest (%) | Current interest (%) | Remarks |
|---|---|---|---|---|
| Australia | WA-536-P | (65%) | —% | Licence expiry^37^ |
| Egypt | Red Sea Block 1 | (45%) | —% | Licence expiry - subsequent to<br> <br>the<br>period |
| USA | GB 895, GB 852, GB<br> <br>851, GB 806, GB 805,<br><br><br>GB 762, GB 677, GB<br> <br>676, GB 630, GB 760,<br><br><br>GB 716, GB 672, GB<br> <br>721 | 40% | 100% | Assignment |
| ^37^ | National Electronic Approval Tracking System (NEATS) will be updated when expiry has been published in the<br>Australian Government Gazette. | |||
| --- | --- | |||
| 16 | First quarter report for period ended 31 March 2025 | |||
| --- | --- | |||
| Production rates | ||||
| --- |
Average daily production rates (100% project) for the quarter ended 31 March 2025:
| Woodsideshare^38^ | Production rate(100% project,Mboe/d) | Remarks | ||||||
|---|---|---|---|---|---|---|---|---|
| Mar<br><br><br>2025 | Dec<br><br><br>2024 | |||||||
| AUSTRALIA | ||||||||
| NWS Project | ||||||||
| LNG | 30.29 | % | 235 | 258 | Production was lower due to weather events. | |||
| Crude oil and condensate | 30.41 | % | 40 | 45 | ||||
| NGL | 30.35 | % | 8 | 10 | ||||
| Pluto LNG | ||||||||
| LNG | 90.00 | % | 104 | 109 | Production was lower due to unplanned outages. | |||
| Crude oil and condensate | 90.00 | % | 9 | 10 | ||||
| Pluto-KGPInterconnector | ||||||||
| LNG | 100.00 | % | 23 | 24 | ||||
| Crude oil and condensate | 100.00 | % | 1 | 1 | ||||
| NGL | 100.00 | % | 1 | 1 | ||||
| Wheatstone^39^ | ||||||||
| LNG | 12.03 | % | 224 | 220 | Production was higher due to increased reliability. | |||
| Crude oil and condensate | 15.85 | % | 31 | 32 | ||||
| Bass Strait | ||||||||
| Pipeline gas | 46.62 | % | 76 | 85 | Production was lower due to planned maintenance. | |||
| Crude oil and condensate | 44.91 | % | 10 | 12 | ||||
| NGL | 46.21 | % | 16 | 18 | ||||
| Australia Oil | ||||||||
| Ngujima-Yin | 60.00 | % | 13 | 21 | Production was lower due to weather events. | |||
| Okha | 50.00 | % | 7 | 13 | ||||
| Pyrenees | 64.85 | % | 6 | 10 | ||||
| Other | ||||||||
| Pipeline gas^40^ | 42 | 45 | ||||||
| ^38^ | Woodside share reflects the net realised interest for the period. | |||||||
| --- | --- | |||||||
| ^39^ | The Wheatstone asset processes gas from several offshore gas fields, including the Julimar and Brunello fields,<br>for which Woodside has 65% participating interest and is the operator. | |||||||
| --- | --- | |||||||
| ^40^ | Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.<br> | |||||||
| --- | --- | |||||||
| 17 | First quarter report for period ended 31 March 2025 | |||||||
| --- | --- | |||||||
| Woodsideshare^41^ | Production rate(100% project,Mboe/d) | Remarks | ||||||
| --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Mar<br><br><br>2025 | Dec<br><br><br>2024 | |||||||
| INTERNATIONAL | ||||||||
| Atlantis | ||||||||
| Crude oil and condensate | 38.50 | % | 71 | 63 | Production was higher due to increased reliability and a successful intervention campaign. | |||
| NGL | 38.50 | % | 4 | 4 | ||||
| Pipeline gas | 38.50 | % | 8 | 5 | ||||
| Mad Dog | ||||||||
| Crude oil and condensate | 20.86 | % | 137 | 136 | ||||
| NGL | 20.86 | % | 6 | 4 | ||||
| Pipeline gas | 20.86 | % | 3 | 3 | ||||
| Shenzi | ||||||||
| Crude oil and condensate | 64.69 | % | 40 | 31 | Production was higher due to increased reliability. | |||
| NGL | 64.79 | % | 2 | 2 | ||||
| Pipeline gas | 64.66 | % | 1 | 1 | ||||
| Trinidad & Tobago | ||||||||
| Crude oil and condensate | 79.13 | %^42^ | 1 | 3 | Production was lower due to reservoir decline. | |||
| Pipeline gas | 50.35 | %^42^ | 53 | 57 | ||||
| Sangomar | ||||||||
| Crude oil | 78.45 | %^42^ | 99 | 95 | Production was higher due to increased reliability. | |||
| ^41^ | Woodside share reflects the net realised interest for the period. | |||||||
| --- | --- | |||||||
| ^42^ | Operations governed by production sharing contracts. | |||||||
| --- | --- | |||||||
| 18 | First quarter report for period ended 31 March 2025 | |||||||
| --- | --- |
Disclaimer and important notice
Forward looking statements
This report contains forward-looking statements with respect to Woodside’s business and operations, market conditions, results of operations and financial condition, including for example, but not limited to, outcomes of transactions, statements regarding long-term demand for Woodside’s products, potential investment decisions, development, completion and execution of Woodside’s projects, expectations regarding future capital expenditures, the payment of future dividends and the amount thereof, future results of projects, operating activities and new energy products, expectations and plans for renewables production capacity and investments in, and development of, renewables projects, expectations and guidance with respect to production, capital and exploration expenditure and gas hub exposure. All statements, other than statements of historical or present facts, are forward-looking statements and generally may be identified by the use of forward-looking words such as ‘guidance’, ‘foresee’, ‘likely’, ‘potential’, ‘anticipate’, ‘believe’, ‘aim’, ‘aspire’, ‘estimate’, ‘expect’, intend’, ‘may’, ‘target’, ‘plan’, ‘strategy’, ‘forecast’, ‘outlook’, ‘project’, ‘schedule’, ‘will’, ‘should’, ‘seek’, and other similar words or expressions. Similarly, statements that describe the objectives, plans, goals or expectations of Woodside are forward-looking statements.
Forward-looking statements in this report are not guidance, forecasts, guarantees or predictions of future events or performance, but are in the nature of future expectations that are based on management’s current expectations and assumptions. Those statements and any assumptions on which they are based are subject to change without notice and are subject to inherent known and unknown risks, uncertainties, contingencies and other factors, many of which are beyond the control of Woodside, its related bodies corporate and their respective officers, directors, employees, advisers or representatives. Important factors that could cause actual results to differ materially from those in the forward-looking statements and assumptions on which they are based include, but are not limited to, fluctuations in commodity prices, actual demand for Woodside’s products, currency fluctuations, geotechnical factors, drilling and production results, gas commercialisation, development progress, operating results, engineering estimates, reserve and resource estimates, loss of market, industry competition, sustainability and environmental risks, climate related transition and physical risks, changes in accounting, standards, economic and financial markets conditions in various countries and regions, political risks, the actions of third parties, project delay or advancement, regulatory approvals, the impact of armed conflict and political instability (such as the ongoing conflicts in Ukraine and in the Middle East) on economic activity and oil and gas supply and demand, cost estimates, legislative, fiscal and regulatory developments, including but not limited to those related to the imposition of tariffs and other trade restrictions, and the effect of future regulatory or legislative actions on Woodside or the industries in which it operates, including potential changes to tax laws, and the impact of general economic conditions, inflationary conditions, prevailing exchange rates and interest rates and conditions in financial markets and risks associated with acquisitions, mergers, divestitures and joint ventures, including difficulties integrating or separating businesses, uncertainty associated with financial projections, restructuring, increased costs and adverse tax consequences, and uncertainties and liabilities associated with acquired and divested properties and businesses.
A more detailed summary of the key risks relating to Woodside and its business can be found in the “Risk” section of Woodside’s most recent Annual Report released to the Australian Securities Exchange and in Woodside’s most recent Annual Report on Form 20-F filed with the United States Securities and Exchange Commission and available on the Woodside website at https://www.woodside.com/investors/reports-investor-briefings. You should review and have regard to these risks when considering the information contained in this report.
If any of the assumptions on which a forward-looking statement is based were to change or be found to be incorrect, this would likely cause outcomes to differ from the statements made in this report.
| 19 | First quarter report for period ended 31 March 2025 |
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All forward-looking statements contained in this report reflect Woodside’s views held as at the date of this report and, except as required by applicable law, Woodside does not intend to, undertake to, or assume any obligation to, provide any additional information or update or revise any of these statements after the date of this report, either to make them conform to actual results or as a result of new information, future events, changes in Woodside’s expectations or otherwise.
Investors are strongly cautioned not to place undue reliance on any forward-looking statements. Actual results or performance may vary materially from those expressed in, or implied by, any forward-looking statements. None of Woodside nor any if its related bodies corporate, nor any of their respective officers, directors, employees, advisers or representatives, nor any person named in this report or involved in the preparation of the information in this report, makes any representation, assurance, guarantee or warranty (either express or implied) as to the accuracy or likelihood of fulfilment of any forward-looking statement, or any outcomes, events or results expressed or implied in any forward-looking statement in this report. Past performance (including historical financial and operational information) is given for illustrative purposes only. It should not be relied on as, and is not necessarily, a reliable indicator of future performance, including future security prices.
Other important information
All figures are Woodside share for the quarter ending 31 March 2025, unless otherwise stated.
All references to dollars, cents or $ in this report are to US currency, unless otherwise stated.
References to “Woodside” may be references to Woodside Energy Group Ltd and/or its applicable subsidiaries (as the context requires).
Notes to petroleum reserves and resources
| 1. | The petroleum resource estimates are quoted as at the effective date of 31 March 2025, net Woodside share.<br>For details of Woodside’s year end 2024 reserves position, see the Reserves and Resources Statement included in the 2024 Annual Report. |
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| 2. | All numbers are internal estimates produced by Woodside. Estimates of reserves and contingent resources should<br>be regarded only as estimates that may change over time as additional information becomes available. |
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| 3. | The reference point is defined as the outlet of the floating production storage and offloading facility (FPSO).<br> |
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| 4. | ‘Reserves’ are estimated quantities of petroleum that have been demonstrated to be producible from<br>known accumulations in which the company has a material interest from a given date forward, at commercial rates, under presently anticipated production methods, operating conditions, prices, and costs. Woodside reports reserves inclusive of all fuel<br>consumed in operations. Woodside estimates and reports its proved reserves in accordance with SEC regulations which are also compliant with the 2018 Society of Petroleum Engineers (SPE)/World Petroleum Council (WPC)/American Association of Petroleum<br>Geologists (AAPG)/Society of Petroleum Evaluation Engineers (SPEE) Petroleum Resources Management System (PRMS) (SPE-PRMS) guidelines. SEC-compliant proved reserves<br>estimates use a more restrictive, rules-based approach and are generally lower than estimates prepared solely in accordance with SPE-PRMS guidelines due to, among other things, the requirement to use commodity<br>prices based on the average of first of month prices during the 12-month period in the reporting company’s fiscal year. Woodside estimates and reports its proved plus probable reserves in accordance with SPE-PRMS guidelines which are not compliant with SEC regulations. |
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| 5. | Assessment of the economic value in support of an SPE-PRMS<br>(2018) reserves and resources classification, uses Woodside Portfolio Economic Assumptions (Woodside PEAs). The Woodside PEAs are reviewed on an annual basis, or more often if required. The review is based on historical data and forecast<br>estimates for economic variables such as product prices and exchange rates. The Woodside PEAs are approved by the Woodside Board. Specific contractual arrangements for individual projects are also taken into account. |
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| 6. | Woodside uses both deterministic and probabilistic methods for the estimation of reserves and contingent<br>resources at the field and project levels. All proved reserves estimates have been estimated using deterministic methods and reported on a net interest basis in accordance with the SEC regulations and have been determined in accordance with SEC Rule<br>4-10(a) of Regulation S-X. |
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| 20 | First quarter report for period ended 31 March 2025 |
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| 7. | ‘MMboe’ means millions (10^6^) of barrels of<br>oil equivalent. Natural gas volumes are converted to oil equivalent volumes via a constant conversion factor, which for Woodside is 5.7 Bcf of dry gas per 1 MMboe. All volumes are reported at standard oilfield conditions of 14.696 psi (101.325 kPa)<br>and 60 degrees Fahrenheit (15.56 degrees Celsius). |
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| 8. | ‘Proved reserves’ are those quantities of crude oil, condensate, natural gas and NGLs that, by<br>analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward from known reservoirs and under existing economic conditions, operating methods, operating contracts, and<br>government regulations. Proved reserves are estimated and reported on a net interest basis in accordance with the SEC regulations and have been determined in accordance with SEC Rule 4-10(a) of Regulation S-X. |
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| 9. | ‘Undeveloped reserves’ are those reserves for which wells and facilities have not been installed or<br>executed but are expected to be recovered through future significant investments. |
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| 10. | ‘Probable reserves’ are those reserves which analysis of geological and engineering data suggests are<br>more likely than not to be recoverable. Proved plus probable reserves represent the best estimate of recoverable quantities. Where probabilistic methods are used, there is at least a 50% probability that the actual quantities recovered will equal or<br>exceed the sum of estimated proved plus probable reserves. Proved plus probable reserves are estimated and reported in accordance with SPE-PRMS guidelines and are not compliant with SEC regulations.<br> |
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| 11. | The estimates of petroleum reserves and contingent resources are based on and fairly represent information and<br>supporting documentation prepared by, or under the supervision of, Mr Benjamin Ziker, Woodside’s Vice President Reserves and Subsurface, who is a full-time employee of the company and a member of the Society of Petroleum Engineers. The reserves<br>and resources estimates included in this announcement are issued with the prior written consent of Mr Ziker. Mr Ziker’s qualifications include a Bachelor of Science (Chemical Engineering) from Rice University (Houston, Texas, USA) and 26 years<br>of relevant experience. |
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Additional information for US investors concerning resource estimates
Woodside is an Australian company listed on the Australian Securities Exchange and the New York Stock Exchange. As noted above, Woodside estimates and reports its proved reserves in accordance with SEC regulations, which are also compliant with SPE-PRMS guidelines, and estimates and reports its proved plus probable reserves and 2C contingent resources in accordance with SPE-PRMS guidelines. Woodside reports all petroleum resource estimates using definitions consistent with SPE-PRMS.
The SEC prohibits oil and gas companies, in their filings with the SEC, from disclosing estimates of oil or gas resources other than ‘reserves’ (as that term is defined by the SEC). In this announcement, Woodside includes estimates of quantities of oil and gas using certain terms, such as ‘proved plus probable (2P) reserves’, ‘best estimate (2C) contingent resources’, ‘reserves and contingent resources’, ‘proved plus probable’, ‘developed and undeveloped’, ‘probable developed’, ‘probable undeveloped’, ‘contingent resources’ or other descriptions of volumes of reserves, which terms include quantities of oil and gas that may not meet the SEC’s definitions of proved, probable and possible reserves, and which the SEC’s guidelines strictly prohibit Woodside from including in filings with the SEC. These types of estimates do not represent, and are not intended to represent, any category of reserves based on SEC definitions, and may differ from and may not be comparable to the same or similarly-named measures used by other companies. These estimates are by their nature more speculative than estimates of proved reserves and would require substantial capital spending over a significant number of years to implement recovery, and accordingly are subject to substantially greater risk of not being recovered by Woodside. In addition, actual locations drilled and quantities that may be ultimately recovered from Woodside’s properties may differ substantially. Woodside has made no commitment to drill, and likely will not drill, all drilling locations that have been attributable to these quantities. US investors are urged to consider closely the disclosures in Woodside’s most recent Annual Report on Form 20-F filed with the SEC and available on the Woodside website at https://www.woodside.com/investors/reports-investor-briefings and its other filings with the SEC, which are available at www.sec.gov.
| 21 | First quarter report for period ended 31 March 2025 |
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| Glossary, units of measure and conversion factors | |
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Refer to the Glossary in the Annual Report 2024 for definitions, including carbon related definitions.
| Product | Unit | Conversion factor |
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| Natural gas | 5,700 scf | 1 boe |
| Condensate | 1 bbl | 1 boe |
| Oil | 1 bbl | 1 boe |
| Natural gas liquids | 1 bbl | 1 boe |
| Facility | Unit | LNG Conversion factor |
| Karratha Gas Plant | 1 tonne | 8.08 boe |
| Pluto Gas Plant | 1 tonne | 8.34 boe |
| Wheatstone | 1 tonne | 8.27 boe |
The LNG conversion factor from tonne to boe is specific to volumes produced at each facility and is based on gas composition which may change over time.
| Term | Definition |
|---|---|
| bbl | barrel |
| bcf | billion cubic feet of gas |
| boe | barrel of oil equivalent |
| GJ | gigajoule |
| Mbbl | thousand barrels |
| Mbbl/d | thousand barrels per day |
| Mboe | thousand barrels of oil equivalent |
| Mboe/d | thousand barrels of oil equivalent per day |
| Mcf | thousand cubic feet of gas |
| MMboe | million barrels of oil equivalent |
| MMBtu | million British thermal units |
| MMscf/d | million standard cubic feet of gas per day |
| PJ | petajoules |
| scf | standard cubic feet of gas |
| TJ | terajoule |
| 22 | First quarter report for period ended 31 March 2025 |
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