WDS Woodside Energy Group Ltd

Sangomar underpins record annual production

Operations

• Outstanding production from Sangomar with 75 Mboe/day produced in the quarter, driving record full-year production of 194 MMboe (530 Mboe/day), at the top end of the 2024 full-year production guidance range.
• Quarterly production of 51.4 MMboe. (559 Mboe/day), down 3% from Q3 2024 due to lower seasonal demand at Bass Strait and an unplanned shutdown at Pluto, partly offset by increased production at Sangomar.
• Quarterly revenue of $3,470 million, down 6% from Q3 2024 primarily due to lower seasonal demand at Bass Strait, partly offset by higher third-party LNG trades.
• Sold 33.6% of produced LNG at prices linked to gas hub indices in the quarter (12.8% of total equity production), realising a 31% premium compared to oil-linked pricing.

Projects

• The Scarborough Energy project was 78% complete at the end of the quarter, with the final Pluto Train 2 modules arriving at the Pluto LNG site in December. The project remains on target for first LNG cargo in 2026.
• The Trion project was 20% complete at the end of the quarter, with construction of the floating production unit commencing in November. First oil is targeted for 2028.
• Continued construction of the Beaumont New Ammonia project with Phase 1 of the project on track for start up in the second half of 2025.

Portfolio Developments

• Simplified Woodside’s Australian portfolio and consolidated focus on operated LNG assets, by entering into an asset swap with Chevron.1
• Signed an engineering, procurement and construction (EPC) contract with Bechtel for the Louisiana LNG foundation development. FID is targeted from Q1 2025.
• Completed the sale of a 15.1% non-operating participating interest in the Scarborough Joint Venture to JERA for approximately US$1.4 billion.

Woodside Energy Group (ASX: WDS) (NYSE: WDS):

Woodside CEO Meg O’Neill said Woodside is delivering on its growth strategy while taking steps to sharpen its focus on high-value core assets.

“Our high-quality assets continued to deliver outstanding performance in the quarter, underpinned by Sangomar producing 75 thousand barrels of oil equivalent per day at 95% reliability, driving record annual production of 194 million barrels of oil equivalent. We also saw a strong contribution from Mad Dog in the Gulf of Mexico, with a full year of Argos production at peak rates.

“At the same time, we made important progress with our growth projects, including the arrival of the final Pluto Train 2 modules for our Scarborough Energy Project, which remains on track for first LNG in 2026. We were also pleased to welcome JERA, another strategic partner, into the Scarborough Joint Venture.

“The Trion Project has also transitioned into the construction phase, with the first steel cut for the floating production unit, and we remain on track for 2028 first oil.

“We continued to move at pace on our recently acquired Louisiana LNG development, signing an engineering, procurement and construction contract with Bechtel to support final investment decision readiness from the first quarter of 2025. We also progressed the sell-down process, which has attracted strong interest from high-quality potential partners. It is encouraging to see the growing level of support for LNG opportunities in the US from capital markets, including the recognition of the potential additional value unlocked by strong marketing capabilities. Woodside's business model is uniquely placed to deliver compelling long-term value in the US LNG market.

“Equally exciting was the progress at our re-named Beaumont New Ammonia project, with construction of Train 1 underway as we work towards Phase 1 project completion and operations readiness in the second half of 2025.

“With such a strong growth journey ahead of us, we recognise the need to remain focused. In the quarter, we announced an asset swap with Chevron, which streamlines our Australia portfolio by trading our equity in Wheatstone to increase our position in North West Shelf to 50% and support short-term cash generation.

"This agreement positions Woodside to continue providing energy for local and global customers from the North West Shelf, further supported by the Western Australian Government’s environmental approval for the North West Shelf Project Extension received during the quarter.

“We will continue to pursue targeted and strategic opportunities to simplify our business and sharpen our focus to deliver long-term shareholder value.

“Our commitment to the domestic market was further demonstrated by the execution of gas sales of 77 petajoules in eastern Australia. This highlights the ongoing role of gas in supporting Australian households, businesses and manufacturers. We continued work on optimising facilities and maximising gas production from Bass Strait, while marking the end of 55 years of oil production.

“Conducting our business sustainably underpins our strategy to thrive through the energy transition. Preliminary data shows a 14% reduction in our net equity Scope 1 and 2 emissions in 2024, from our stated starting base. Whilst we are on track to meet our scope 1 and 2 net reduction targets, with the strong start-up of Sangomar, our absolute emissions did increase in 2024. We remain committed to take actions to decarbonise our assets and this has become part of how we run our business every day.

“Over the quarter, we continued to make major contributions to the communities where we operate, awarding our largest-ever Traditional Owner construction contract to locally based company Winyama, which will support the delivery of Scarborough.

“As we officially recognised our 70-year anniversary in 2024, we reflected on our proud history and the contributions of the determined people who built this company. Today, Woodside’s determination to provide energy the world needs and deliver value for our shareholders is stronger than ever. We are building on strong foundations to position Woodside for long-term success,” she said.

Comparative performance at a glance

 

Q4

2024

Q3 2024

Change %

Q4 2023

Change %

YTD

2024

YTD

2023

Change %

Revenue

$ million

3,470

3,679

(6%)

3,355

3%

13,151

14,028

(6%)

Production2

MMboe

51.4

53.1

(3%)

48.1

7%

193.9

187.2

4%

Gas

MMscf/d

1,909

2,001

(5%)

2,010

(5%)

1,931

2,002

(4%)

Liquids

Mbbl/d

224

226

(1%)

170

32%

191

162

18%

Total

Mboe/d

559

577

(3%)

522

7%

530

513

3%

Sales

MMboe

53.8

55.8

(4%)

49.5

9%

203.5

201.5

1%

Gas

MMscf/d

2,115

2,154

(2%)

2,118

—

2,085

2,248

(7%)

Liquids

Mbbl/d

214

228

(6%)

166

29%

190

158

20%

Total

Mboe/d

585

606

(3%)

538

9%

556

552

1%

Average realised price

$/boe

63

65

(3%)

67

(6%)

64

69

(7%)

Capital expenditure3

$ million

2,681

3,033

(12%)

1,566

71%

8,126

5,701

43%

Capex excl. acquisitions

$ million

1,396

1,133

23%

1,566

(11%)

4,941

5,701

(13%)

Acquisitions4

$ million

1,285

1,900

(32%)

–

100%

3,185

–

100%

 

 

 

 

 

 

 

 

 

 

2024 full-year guidance comparison

Q3 Guidance

Full-year result

Production

MMboe

189 - 195

193.9

(516 - 533 Mboe/day)

(530 Mboe/day)

Capital expenditure (excl acquisitions and other equity changes)

$ billion

4.8 - 5.2

4.9

Gas hub exposure5

% of produced LNG

33 - 37

34.4

 

 

 

Operations

Pluto LNG

• LNG reliability was 92.2% for the quarter following an unplanned five day shutdown of the Pluto facilities in November. Full-year LNG reliability at Pluto was 96.1%.
• Achieved highest quarterly production (3.1 MMboe) through the Pluto-KGP Interconnector for the year.

North West Shelf (NWS) Project

• Achieved strong quarterly LNG reliability of 97.2%. Full-year LNG reliability at NWS was 98.3%.
• Received environmental approvals from the Western Australian Government for the North West Shelf Project Extension. The extension is an important step in enabling the long-term processing of North West Shelf Joint Venture (NWS JV) field resources and third-party resources through the Karratha Gas Plant. The Federal Government approvals process is ongoing. As part of the approval, the NWS JV committed to a range of environmental management measures, including a significant reduction in air emissions, along with greenhouse gas emissions management measures.
• LNG Train 2 was taken offline as preparations for permanent retirement are underway. The train retirement is expected to reduce emissions by approximately 0.3 million tonnes per annum CO2 equivalent (Woodside share, at 33% working interest).

Bass Strait

• Completed the Gippsland Asset Streamlining project with final crude oil from the Cobia platform processed prior to closure of the Crude Stabilisation Plant at Longford.
• Production increased from the Kipper field following successful startup of gas compression facilities.

Sangomar

• Achieved outstanding production of 95 Mboe/day (100%, 75 Mboe/day Woodside share) from the Sangomar field, with a total of 17 cargoes exported from start up to the end of December 2024.
• Successfully completed FPSO commissioning and start-up activities including the gas and water injection systems while also achieving 94% reliability for the quarter.
• Continued to expand the market for Sangomar crude with the grade being supplied into the US for the first time in Q4.

Gulf of Mexico

• Completed a planned shutdown at Shenzi to proactively address integrity and reliability scopes.
• Restored a key Shenzi well to production in November 2024 following an unplanned outage.
• Completed a planned offshore facility shutdown and commenced an infill development well at Mad Dog A-Spar.
• Maintained peak production of ~130 kbbl/d and commenced an infill injector well with plans to complete the well in Q1 2025 at Mad Dog Argos.

Marketing

• Sold 33.6% of produced LNG at prices linked to gas hub indices in the quarter (34.4% full-year 2024), realising a 31% premium compared to oil linked pricing. This represents 12.8% of Woodside’s total equity production in the quarter (15.0% full-year 2024).
• Achieved record quantity of trucked LNG deliveries of approximately 556 TJ, equivalent to 540 trailers, to customers in northern Western Australia.
• Executed incremental Western Australian gas sales of 7.3 PJ (full-year of 73.5 PJ) for delivery across 2025 and 2026. Woodside continues to engage with the Western Australian domestic market on additional supply requirements for 2025, 2026 and 2027.
• Completed eastern Australian Expression of Interest process with executed sales totalling 77.4 PJ across 2025 and 2026.

Projects

Scarborough Energy Project

• The Scarborough and Pluto Train 2 project was 78% complete at the end of the quarter (excluding Pluto Train 1 modifications).
• Fabrication of the floating production unit (FPU) hull and topsides is proceeding ahead of FPU integration activities planned in 2025.
• Completed installation and pre-commissioning activities of the 433km trunkline.
• The final of the 51 Pluto Train 2 modules were delivered and installed in place at the Pluto LNG site.
• Announced Woodside’s largest-ever Traditional Owner construction contract to Winyama Contracting Group for the delivery of civil works for the Pluto Train 1 Modifications project. Mobilisation for the civil works has commenced and module construction is ramping up.
• Completed the sale of a 15.1% non-operating participating interest in the Scarborough Joint Venture to JERA for approximately $1.4 billion.6
• First LNG cargo is targeted for 2026.

Trion

• Trion was 20% complete at the end of the quarter.
• Awarded contracts for drilling and completion services, gas gathering line installation and the build and lease of the floating storage and offloading vessel (FSO).
• Construction of the semi-submersible floating production unit (FPU) and the fabrication of the subsea flexible piping commenced. Subsea equipment manufacturing progressed.

Louisiana LNG

• Completed the acquisition of Tellurian Inc. (Tellurian) and its US Gulf Coast Driftwood LNG development which was renamed Louisiana LNG.
• Signed a lump sum turnkey engineering, procurement and construction (EPC) contract with Bechtel for the three train, 16.5 million tonnes per annum foundation development.
• Continued site works under a limited notice to proceed with Bechtel. Site works are focused on piling, dry excavation and marine offloading facilities.
• Progressed sell-down opportunities for Louisiana LNG. Strong interest has been received from potential project partners.
• Targeting final investment decision (FID) readiness from Q1 2025.

Beaumont New Ammonia

• In October 2024, the tragic death of an employee of one of OCI’s construction contractors occurred at the project site. Woodside continues to work with local authorities, OCI and the contractor company to understand root causes.
• Construction of Train 1 continues with OCI managing the project under the Construction Management Agreement. The project handover is subject to cost, schedule, and performance guarantees from OCI.7
• Woodside continues to work closely with OCI in preparation for operations readiness. Phase 1 of the project is on track to be completed in the second half of 2025.
• The Beaumont Clean Ammonia project has been renamed to Beaumont New Ammonia to reflect change of ownership and the production of a new, lower-carbon ammonia product following ExxonMobil’s carbon, capture and storage (CCS) facility becoming operational.

Decommissioning

• Safely recovered and transported the Griffin Riser Turret Mooring (RTM) to the Australian Marine Complex at Henderson, Western Australia where the RTM will be disassembled and components recycled or reused.
• Continued ongoing decommissioning campaigns including the plugging and abandoning of three wells at Stybarrow, and removal of multiple moorings, structures, and wellheads across a number of fields offshore Western Australia. In 2024, Woodside successfully plugged and abandoned seven of ten Stybarrow wells, recovered more than 90 subsea structures including wellheads, Xmas trees and manifolds, and recovered 149 km of pipe.
• Continued decommissioning activities at Bass Strait, completing the plug and abandonment of wells on the Perch and Dolphin facilities.

Exploration and development

Browse

• Continued activities in support of the Browse to North West Shelf Project, including ongoing regulatory engagement in support of key approvals, progressing commercial discussions and work to optimise the upstream development concept.
• Referred the Browse carbon capture and storage (CCS) system to the Commonwealth regulator in October 2024 for assessment, in accordance with the Environment Protection and Biodiversity Conservation Act 1999. This seeks environmental approval of the Browse CCS system as a separate but related proposal to the Browse to North West Shelf Project.

Calypso

• Progressed pre-FEED engineering studies and subsurface studies to mature the technical definition of the development concept.
• Fiscal negotiations advanced with the Government of Trinidad and Tobago and commercial discussions continued with key stakeholders to evaluate options to monetise the resource.

Sunrise

• The Sunrise Joint Venture (SJV) participants continued negotiations with the Australian and Timor-Leste Governments to progress a new Production Sharing Contract, Petroleum Mining Code and fiscal regime.
• The SJV completed a Concept Study Report considering multiple potential Greater Sunrise development scenarios. The SJV participants are reviewing the outcomes of this report.

Exploration

• On the North El Dabaa Offshore (Block 4) Licence in Egypt, the Khendjer-1X well (non-operated) was drilled in the quarter and did not encounter hydrocarbons. Post-well analysis and learnings integration are ongoing.
• In Namibia, Woodside’s option period to acquire at least a 56% interest in Petroleum Exploration Licence 87 began upon receiving a seismic license in November. Woodside is currently evaluating seismic data in support of the decision on or before 18 May 2025.

New energy and carbon solutions

H2OK

• Woodside continues to take a disciplined approach to H2OK and has made a strategic decision to delay FID, prioritising Beaumont New Ammonia. Work will continue to improve project competitiveness and secure binding offtake agreements.
• Woodside is reviewing the final 45V Clean Hydrogen Production Tax Credit regulations released by the United States Department of Treasury in January 2025.

Heliogen

• Woodside has concluded its collaboration with Heliogen on Project Capella, with both parties deciding to not pursue the construction phase of the project. Woodside and Heliogen continue to evaluate opportunities for further collaboration in deploying concentrated solar power technology.

NeoSmelt

• Woodside will join BHP, Rio Tinto, and BlueScope as part of the NeoSmelt project in Western Australia as energy supplier, subject to finalising commercial arrangements.8
• The NeoSmelt project aims to prove Pilbara iron ore can be used to produce molten iron with reduced CO2 emissions using new technologies and lower carbon energy.

Carbon capture and storage (CCS) opportunities

• Completed the appraisal campaign for the proposed Bonaparte CCS project, with successful drilling of two appraisal wells and the acquisition of West Peron marine 3D seismic.

Carbon Credits Portfolio

• Signed an amendment to expand the reforestation of an additional 2,400 hectares of land in the Chaco region in Paraguay to generate 0.8 million carbon credits. This brings Woodside’s total investment to 7,400 hectares of land, and is expected to generate a total of ~ 2.4 million carbon credits over 40 years.

Corporate activities

Woodside and Chevron asset swap

• In December 2024 Woodside and Chevron agreed to an asset swap under which Woodside will acquire Chevron’s interest in the North West Shelf (NWS) Project, the NWS Oil Project and the Angel Carbon Capture and Storage (CCS) Project, and transfer all of its interest in both the Wheatstone and Julimar Brunello Projects to Chevron. Chevron will also make a cash payment to Woodside of up to $400 million.9

Hedging

• During the quarter 11.4 MMboe of 2025 production was hedged, bringing the total 2025 hedging to 30 MMboe at an average price of approximately $78.7 per barrel.
• Woodside also has a hedging program for Corpus Christi LNG volumes designed to protect against downside pricing risk. These hedges are Henry Hub (HH) and Title Transfer Facility (TTF) commodity swaps. Approximately 94% of 2025 and 67% of 2026 volumes have been hedged.
• The realised value of all hedged positions for the year ended 31 December 2024 is a pre-tax expense of approximately $46 million, with a $202 million expense related to oil price hedges offset by $96 million profit related to LNG hedges and $60 million profit related to other hedge positions. Hedging expense will be included in “other expenses” in the full-year financial statements.

Delisting from the London Stock Exchange

• Woodside delisted from the London Stock Exchange on 20 November 2024. Woodside’s primary listing on the Australian Securities Exchange and its American Depositary Receipts program on the New York Stock Exchange are not affected by the delisting of Woodside’s shares from the London Stock Exchange.

2024 Full-Year Results and teleconference

• Woodside’s 2024 Annual Report, 2024 Climate Update and associated investor briefing will be released to the market on Tuesday, 25 February 2025. These will also be available on Woodside’s website at http://www.woodside.com/
• A teleconference providing an overview of the full-year 2024 results and a question and answer session will be hosted by Woodside CEO and Managing Director, Meg O’Neill, and Chief Financial Officer, Graham Tiver, on Tuesday, 25 February 2025 at 10:00 AEDT / 07:00 AWST / 17:00 CST (Monday, 24 February 2025).
• We recommend participants pre-register 5 to 10 minutes prior to the event with one of the following links:
  • https://webcast.openbriefing.com/wds-fyr-24/ to view the presentation and listen to a live stream of the question and answer session
  • https://s1.c-conf.com/diamondpass/10044744-jh76t5.html to participate in the question and answer session. Following pre-registration, participants will receive the teleconference details and a unique passcode.

Annual General Meeting

• Woodside’s Annual General Meeting will be held at 10:00am (AWST) on Thursday 8 May 2025 in Perth, Western Australia and online. The closing date for receipt of director nominations is 3 March 2025.

2025 full-year guidance

Production

• Woodside’s full-year 2025 production guidance is 186 – 196 MMboe (510 – 537 Mboe/day). This excludes volumes from Beaumont New Ammonia.
• The approximate split by product type is:

LNG

 

 

~40%

Pipeline gas

 

 

~20%

Crude and condensate

 

 

~35%

Natural gas liquids

 

 

~5%

 

Capital expenditure

• Woodside’s full-year 2025 capital expenditure guidance is $4.5 - 5.0 billion, this excludes the impact of any subsequent asset sell-downs, future acquisitions or other equity changes. It also excludes Louisiana LNG expenditure.10
• The main activities are:

Scarborough11

 

 

~35%

Trion12

 

 

~20%

Australia Other13

 

 

~20%

International Other

 

 

~10%

Beaumont New Ammonia14

 

 

~10%

 

 

 

 

Gas hub exposure

• Woodside expects approximately 28% - 35% of its 2025 produced LNG to be sold at prices linked to gas hub indices.15

Production summary

 

 

 

 

 

 

 

 

 

Q4 2024

Q3 2024

Q4 2023

YTD 2024

YTD 2023

Gas

MMscf/d

1,909

2,001

2,010

1,931

2,002

Liquids

Mbbl/d

224

226

170

191

162

Total

Mboe/d

559

577

522

530

513

 

 

Q4 2024

Q3 2024

Q4 2023

YTD 2024

YTD 2023

AUSTRALIA

 

 

 

 

 

 

LNG

 

 

 

 

 

 

North West Shelf

Mboe

7,117

7,029

7,798

29,426

32,807

Pluto16

Mboe

11,232

12,007

12,407

46,719

45,587

Wheatstone

Mboe

2,460

2,565

2,505

9,341

10,159

Total

Mboe

20,809

21,601

22,710

85,486

88,553

 

 

 

 

 

 

 

Pipeline gas

 

 

 

 

 

 

Bass Strait

Mboe

3,140

4,069

3,206

12,978

15,100

Other17

Mboe

4,136

4,016

3,438

15,278

13,027

Total

Mboe

7,276

8,085

6,644

28,256

28,127

 

 

 

 

 

 

 

Crude oil and condensate

 

 

 

 

 

 

North West Shelf

Mbbl

1,250

1,265

1,359

5,187

5,867

Pluto16

Mbbl

911

966

994

3,741

3,630

Wheatstone

Mbbl

423

474

495

1,739

1,805

Bass Strait

Mbbl

482

701

704

2,178

3,367

Macedon & Pyrenees

Mbbl

617

633

653

1,466

2,731

Ngujima-Yin

Mbbl

1,143

1,231

1,203

4,234

3,212

Okha

Mbbl

616

615

616

2,188

2,076

Total

Mboe

5,442

5,885

6,024

20,733

22,688

 

 

 

 

 

 

 

NGL

 

 

 

 

 

 

North West Shelf

Mbbl

274

288

275

1,131

1,182

Pluto16

Mbbl

58

55

58

226

206

Bass Strait

Mbbl

740

1,152

1,026

3,665

4,320

Total

Mboe

1,072

1,495

1,359

5,022

5,708

 

 

 

 

 

 

 

Total Australia 18

Mboe

34,599

37,066

36,737

139,497

145,076

Mboe/d

376

403

399

381

397

 

 

Q4 2024

Q3 2024

Q4 2023

YTD 2024

YTD 2023

INTERNATIONAL

 

 

 

 

 

 

Pipeline gas

 

 

 

 

 

 

Gulf of Mexico

Mboe

305

327

314

1,316

1,343

Trinidad & Tobago

Mboe

2,425

2,289

2,779

8,953

10,151

Other19

Mboe

-

-

-

-

47

Total

Mboe

2,730

2,616

3,093

10,269

11,541

 

 

 

 

 

 

 

Crude oil and condensate

 

 

 

 

 

 

Atlantis

Mbbl

2,238

2,351

2,763

9,049

10,965

Mad Dog

Mbbl

2,607

2,363

2,054

10,679

6,808

Shenzi

Mbbl

1,832

2,047

2,712

8,617

10,065

Trinidad & Tobago

Mbbl

140

143

284

503

1,076

Sangomar

Mbbl

6,901

5,902

-

13,343

-

Other19

Mbbl

81

81

81

324

237

Total

Mboe

13,799

12,887

7,894

42,515

29,151

 

 

 

 

 

 

 

NGL

 

 

 

 

 

 

Gulf of Mexico

Mbbl

320

515

344

1,583

1,387

Other19

Mbbl

-

-

-

-

27

Total

Mboe

320

515

344

1,583

1,414

 

 

 

 

 

 

 

Total International

Mboe

16,849

16,018

11,331

54,367

42,106

Mboe/d

183

174

123

149

115

 

 

 

 

 

 

 

Total Production

Mboe

51,448

53,084

48,068

193,864

187,182

Mboe/d

559

577

522

530

513

Product sales

 

 

 

 

 

 

 

 

 

Q4 2024

Q3 2024

Q4 2023

YTD 2024

YTD 2023

Gas

MMscf/d

2,115

2,154

2,118

2,085

2,248

Liquids

Mbbl/d

214

228

166

190

158

Total

Mboe/d

585

606

538

556

552

 

 

Q4 2024

Q3 2024

Q4 2023

YTD 2024

YTD 2023

AUSTRALIA

 

 

 

 

 

 

LNG

 

 

 

 

 

 

North West Shelf

Mboe

6,753

7,353

7,367

29,195

34,573

Pluto

Mboe

10,490

12,014

12,130

45,766

45,654

Wheatstone20

Mboe

2,280

3,048

2,473

10,181

9,676

Total

Mboe

19,523

22,415

21,970

85,142

89,903

 

 

 

 

 

 

 

Pipeline gas

 

 

 

 

 

 

Bass Strait

Mboe

3,320

4,163

3,341

13,561

15,042

Other21

Mboe

4,058

3,816

3,684

14,203

12,906

Total

Mboe

7,378

7,979

7,025

27,764

27,948

 

 

 

 

 

 

 

Crude oil and condensate

 

 

 

 

 

 

North West Shelf22

Mbbl

1,203

1,253

514

5,574

4,669

Pluto

Mbbl

1,093

858

614

3,874

3,070

Wheatstone

Mbbl

319

360

349

1,674

1,697

Bass Strait

Mbbl

518

662

410

2,048

2,934

Ngujima-Yin

Mbbl

1,006

1,082

1,352

4,105

3,201

Okha

Mbbl

653

618

1

2,461

1,951

Macedon & Pyrenees

Mbbl

472

498

1,054

1,466

2,605

Total

Mboe

5,264

5,331

4,294

21,202

20,127

 

 

 

 

 

 

 

NGL

 

 

 

 

 

 

North West Shelf

Mbbl

252

249

253

1,022

941

Pluto

Mbbl

53

52

49

209

336

Bass Strait

Mbbl

303

1,142

1,370

2,591

4,341

Total

Mboe

608

1,443

1,672

3,822

5,618

 

 

 

 

 

 

 

Total Australia

Mboe

32,773

37,168

34,961

137,930

143,596

Mboe/d

356

404

380

377

393

 

 

Q4 2024

Q3 2024

Q4 2023

YTD 2024

YTD 2023

INTERNATIONAL

 

 

 

 

 

 

Pipeline gas

 

 

 

 

 

 

Gulf of Mexico

Mboe

231

286

357

1,139

1,362

Trinidad & Tobago

Mboe

2,802

2,004

2,611

8,869

10,180

Other23

Mboe

6

2

6

19

26

Total

Mboe

3,039

2,292

2,974

10,027

11,568

 

 

 

 

 

 

 

Crude oil and condensate

 

 

 

 

 

 

Atlantis

Mbbl

2,108

2,436

2,976

8,983

10,796

Mad Dog

Mbbl

2,629

2,489

2,209

10,787

6,819

Shenzi

Mbbl

1,730

2,032

2,716

8,544

10,164

Trinidad & Tobago

Mbbl

53

221

316

345

1,219

Sangomar

Mbbl

6,793

6,070

-

12,863

-

Other23

Mbbl

42

45

53

206

242

Total

Mboe

13,355

13,293

8,270

41,728

29,240

 

 

 

 

 

 

 

NGL

 

 

 

 

 

 

Gulf of Mexico

Mbbl

303

388

435

1,558

1,519

Other23

Mbbl

4

1

2

11

13

Total

Mboe

307

389

437

1,569

1,532

 

 

 

 

 

 

 

Total International

Mboe

16,701

15,974

11,681

53,324

42,340

Mboe/d

182

174

127

146

116

 

 

 

 

 

 

 

MARKETING24

 

 

 

 

 

 

LNG

Mboe

4,196

2,077

2,209

10,952

14,553

Liquids25

Mboe

160

555

618

1,323

1,047

Total

Mboe

4,356

2,632

2,827

12,275

15,600

 

 

 

 

 

 

 

Total Marketing

Mboe

4,356

2,632

2,827

12,275

15,600

 

 

 

 

 

 

 

Total sales

Mboe

53,830

55,774

49,469

203,529

201,536

Mboe/d

585

606

538

556

552

Revenue

 

 

 

 

 

 

 

Q4 2024

Q3 2024

Q4 2023

YTD 2024

YTD 2023

AUSTRALIA

 

 

 

 

 

North West Shelf

497

520

509

2,133

3,021

Pluto

853

920

1,011

3,409

3,789

Wheatstone26

199

237

208

861

982

Bass Strait

217

344

225

1,031

1,143

Macedon

49

48

54

196

199

Ngujima-Yin

84

94

128

361

292

Okha

50

51

-

197

159

Pyrenees

40

44

94

128

233

Total Australia

1,989

2,258

2,229

8,316

9,818

 

 

 

 

 

 

INTERNATIONAL

 

 

 

 

 

Atlantis

156

194

241

714

852

Mad Dog

183

192

178

828

532

Shenzi

124

160

217

679

794

Trinidad & Tobago27

66

63

103

228

368

Sangomar

484

464

-

948

-

Other28

2

3

4

15

18

Total International

1,015

1,076

743

3,412

2,564

 

 

 

 

 

 

Marketing revenue29

410

285

332

1,187

1,453

 

 

 

 

 

 

Total sales revenue30

3,414

3,619

3,304

12,915

13,835

 

 

 

 

 

 

Processing revenue

53

54

49

220

184

Shipping and other revenue

3

6

2

16

9

 

 

 

 

 

 

Total revenue

3,470

3,679

3,355

13,151

14,028

Realised prices

 

 

 

 

 

 

 

 

 

 

Units

Q4 2024

Q3 2024

Q4 2023

Units

Q4 2024

Q3 2024

Q4 2023

LNG produced31

$/MMBtu

10.8

10.8

11.5

$/boe

69

68

74

LNG traded32

$/MMBtu

12.6

11.2

11.9

$/boe

80

71

76

Pipeline gas

 

 

 

 

$/boe

33

38

37

Oil and condensate

$/bbl

71

78

82

$/boe

71

78

82

NGL

$/bbl

45

48

24

$/boe

45

48

24

Liquids traded32

$/bbl

67

60

85

$/boe

67

60

85

Average realised price for pipeline gas:

 

 

 

 

 

 

 

Western Australia

 

 

 

 

A$/GJ

6.6

6.5

6.8

East Coast Australia

 

 

 

 

A$/GJ

12.7

14.2

13.4

International

 

 

 

 

$/Mcf

4.2

4.3

4.4

Average realised price

 

 

 

 

$/boe

63

65

67

Dated Brent

 

 

 

 

$/bbl

75

80

84

JCC (lagged three months)

 

 

 

 

$/bbl

86

88

83

WTI

 

 

 

 

$/bbl

70

75

78

JKM

 

 

 

 

$/MMBtu

13.5

12.4

15.0

TTF

 

 

 

 

$/MMBtu

12.8

11.2

13.5

Average realised price decreased 3% from the prior quarter reflecting lower Dated Brent, WTI and JCC.

Capital expenditure (US$ million)

 

 

 

 

 

 

 

Q4 2024

Q3 2024

Q4 2023

YTD 2024

YTD 2023

Exploration and evaluation capitalised34

17

6

43

99

175

Property plant & equipment

1,315

1,076

1,449

4,616

5,270

Other 35

64

51

74

226

256

Sub Total (excluding acquisitions)

1,396

1,133

1,566

4,941

5,701

Acquisitions

1,285

1,900

-

3,185

-

Total

2,681

3,033

1,566

8,126

5,701

 

Q4 2024

Q3 2024

Q4 2023

YTD 2024

YTD 2023

Scarborough

664

438

826

2,239

2,643

Trion

299

225

154

758

273

Sangomar

112

73

211

601

1,019

Other

321

397

375

1,343

1,766

Sub Total (excluding acquisitions)

1,396

1,133

1,566

4,941

5,701

Beaumont New Ammonia Project36

-

1,900

-

1,900

-

Louisiana LNG37

1,067

-

-

1,067

-

Louisiana LNG post-acquisition expenditure

218

-

-

218

-

Sub Total (acquisitions)

1,285

1,900

-

3,185

-

Total

2,681

3,033

1,566

8,126

5,701

Acquisition expenditure represents the purchase consideration for Beaumont New Ammonia of $1,900 million, Louisiana LNG of $1,067 million and post acquisition expenditure for Louisiana LNG of $218 million. The purchase consideration includes the total amount paid for acquiring the companies encompassing all assets and liabilities as part of the transaction.

Other expenditure (US$ million)

 

 

 

 

 

 

 

Q4 2024

Q3 2024

Q4 2023

YTD 2024

YTD 2023

Exploration and evaluation expensed38

140

90

108

330

364

Permit amortisation

2

2

2

10

9

Total

142

92

110

340

373

 

 

 

 

 

 

Trading costs

290

132

181

695

1,068

Exploration or appraisal wells drilled

 

 

 

 

 

 

 

 

 

Region

Permit Area

Well

Target

Interest (%)

Spud Date

Water depth (m)

Actual Well Depth (m)39

Remarks

Egypt

North El Dabaa Offshore (Block 4)

Khendje r-1X

Oil

27% Non-Operator

2 November 2024

2,187

5,458

Plugged and abandoned

Permits and licences

Key changes to permit and licence holdings during the quarter ended 31 December 2024 are noted below.

 

 

 

 

 

Region

Permits or licence areas

Change in interest (%)

Current interest (%)

Remarks

Australia

NT/P86

(100

%)

—

%

Permit Surrender

Egypt

Red Sea Block 3

(30

%)

—

%

Licence Expiry

Red Sea Block 4

(25

%)

—

%

Licence Expiry - Subsequent to the period

Gulf of Mexico

GB 719, GB 720, GB 763, GB 807

(60

%)

—

%

Licence Expiry

GB 574, GB 575, GB 619, GB 529, GB 530, GB 531

17

%

57

%

Assignment

Production rates

Average daily production rates (100% project) for the quarter ended 31 December 2024:

 

Woodside share40

Production rate (100% project, Mboe/d)

Remarks

 

 

Dec 2024

Sep 2024

 

AUSTRALIA

 

 

 

 

NWS Project

 

 

 

 

LNG

30.01%

258

259

Stable production from prior quarter. LNG train 2 cessation of production executed 28 October 2024.

Crude oil and condensate

30.11%

45

46

NGL

30.10%

10

10

 

 

 

 

 

Pluto LNG

 

 

 

 

LNG

90.00%

109

122

Production was lower due to reliability events during the quarter, including process control network fault.

Crude oil and condensate

90.00%

10

10

 

 

 

 

 

Pluto-KGP Interconnector

 

 

 

 

LNG

100.00%

24

21

Production was higher due to increased demand from NWS during the quarter.

Crude oil and condensate

100.00%

1

1

NGL

100.00%

1

1

 

 

 

 

 

Wheatstone41

 

 

 

 

LNG

12.13%

220

232

Production was lower due to reduced reliability during the quarter.

Crude oil and condensate

14.68%

32

33

 

 

 

 

 

Bass Strait

 

 

 

 

Pipeline gas

40.09%

85

102

Production was lower due to reduced seasonal domestic gas demand.

Crude oil and condensate

44.60%

12

16

NGL

45.77%

18

26

 

 

 

 

 

Australia Oil

 

 

 

 

Ngujima-Yin

60.00%

21

22

 

Okha

50.00%

13

13

Pyrenees

64.70%

10

11

 

 

 

 

 

 

Other

 

 

 

 

Pipeline gas42

 

45

44

 

 

Woodside share43

Production rate (100% project, Mboe/d)

Remarks

 

 

Dec

2024

Sep

2024

 

INTERNATIONAL

 

 

 

 

Atlantis

 

 

 

 

Crude oil and condensate

38.50%

63

66

Production lower due to impacts from planned midstream outage.

NGL

38.50%

4

5

Pipeline gas

38.50%

5

7

 

 

 

 

 

Mad Dog

 

 

 

 

Crude oil and condensate

20.86%

136

123

Production higher due to no weather or intervention impacts, partially offset by planned A-Spar TAR.

NGL

20.86%

4

7

Pipeline gas

20.86%

3

2

 

 

 

 

 

Shenzi

 

 

 

 

Crude oil and condensate

64.82%

31

34

Production lower from planned facility shutdown and maintenance as well as unplanned downtime and weather.

NGL

64.88%

2

3

Pipeline gas

64.87%

1

1

 

 

 

 

 

Trinidad & Tobago

 

 

 

 

Crude oil and condensate

58.39%44

3

3

Production was higher following execution of production optimization projects and improved facility uptime.

Pipeline gas

46.63%44

57

49

 

 

 

 

 

Sangomar

 

 

 

 

Crude oil

78.66%

95

81

Production was higher due to improved facility reliability with commissioning and ramp-up completing in the third quarter.

Disclaimer and important notice

Forward looking statements

This report contains forward-looking statements with respect to Woodside’s business, operations, market conditions, results of operations and financial condition, including for example, but not limited to, statements regarding potential investment decisions, development, completion and execution of Woodside’s projects, expectations and guidance with respect to production, capital and exploration expenditure and gas hub exposure, expectations regarding future capital commitment, future cash flows, the outcomes of acquisitions and divestment transactions,including timing and potential benefits thereof, future results of projects, operation activities, new energy products, accounting decisions including impairments, commencement dates under supply arrangements, the potential execution of new supply arrangements, construction and delivery dates, expectations and plans for renewables production capacity and investments in, and development of renewables projects. 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’, ‘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, assumptions 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 include, but are not limited to, fluctuations in commodity prices, actual demand, 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, environmental risks, climate related risks, physical risks, legislative, fiscal and regulatory developments, changes in accounting, standards, economic and financial markets conditions in various countries and regions, political risks, the actions of the 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, 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 businesses, uncertainty associated with financial projections, restructuring, increased costs and adverse tax consequences.

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.

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 December 2024, 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).

Units of measure and conversion factors

 

 

 

Product

Unit

Conversion factor

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

1 Completion of the transaction is subject to customary conditions precedent. See “Woodside simplifies portfolio and unlocks long-term value” announced 19 December 2024 for details. 2 Q4 2024 includes 0.31 MMboe primarily from feed gas purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector. 3 Includes capital additions on property plant and equipment, exploration and evaluation capitalised, other corporate spend and purchase consideration for Beaumont New Ammonia and Louisiana LNG. 4 Purchase consideration for Beaumont New Ammonia and Louisiana LNG. 5 Gas hub indices include Japan Korea Marker (JKM), TTF and National Balancing Point (NBP). It excludes Henry Hub. 6 The sale and purchase agreement is with JERA Scarborough Pty Ltd, a wholly owned subsidiary of JERA Co., Inc. See “Woodside complete sale to JERA of 15.1% in Scarborough”, announced 31 October 2024. 7 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 financial payments to Woodside if the project is delayed beyond September 2025. 8 Energy supply may include hydrogen, natural gas and electricity. Agreement is subject to finalising commercial arrangements. 9 Completion of the transaction is subject to customary conditions precedent. See “Woodside simplifies portfolio and unlocks long-term value” announced 19 December 2024. 10 Total Louisiana LNG expenditure from December 2024 to end of the first quarter 2025 is forecast to be up to $1.3 billion, which is included in the overall estimated cost for the foundation development. 11 Scarborough at 74.9% participating interest, Pluto Train 2 at 51% participating interest. 12 Trion at 60% participating interest. 13 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. 14 Remaining Beaumont New Ammonia acquisition expenditure. 15 Gas hub indices include Japan Korea Marker (JKM), TTF and National Balancing Point (NBP). It excludes HH. 16 Q4 2024 includes 2.23 MMboe of LNG, 0.10 MMboe of condensate and 0.06 MMboe of NGL processed at the Karratha Gas Plant (KGP) through the Pluto-KGP Interconnector. 17 Includes the aggregate Woodside equity domestic gas production from all Western Australian projects. 18 Q4 2024 includes 0.31 MMboe primarily from feed gas purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector. 19 Overriding royalty interests held in the GoM for several producing wells. 20 Includes periodic adjustments reflecting the arrangements governing Wheatstone LNG sales of 0.22 MMboe in Q4 2024, 0.29 MMboe in Q3 2024 and 0.10 MMboe in Q4 2023. 21 Includes the aggregate Woodside equity domestic gas production from all Western Australian projects. 22 Includes reclassification of purchased condensate volumes from NWS JV Participants to Marketing liquids of 0.16 MMboe in Q3 2023 and 0.26 MMboe in Q2 2023. 23 Overriding royalty interests held in the GoM for several producing wells. 24 Purchased volumes sourced from third parties. 25 Includes reclassification of purchased condensate volumes from NWS JV Participants of 0.16 MMboe in Q3 2023 and 0.26 MMboe in Q2 2023. 26 Q4 2024 includes -$14 million, Q3 2024 includes -$28 million and Q4 2023 includes $9 million recognised in relation to periodic adjustments reflecting the arrangements governing Wheatstone LNG sales. These amounts will be included within other income/(expenses) in the financial statements rather than operating revenue. 27 Includes the impact of periodic adjustments related to the production sharing contract (PSC). 28 Overriding royalty interests held in the GoM for several producing wells. 29 Values include revenue generated from purchased LNG and Liquids volumes, as well as the marketing margin on the 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 cargo swaps is recognised net in other income. 30 Total sales revenue excludes all hedging impacts. 31 Realised prices include the impact of periodic adjustments reflecting the arrangements governing Wheatstone LNG sales. 32 Excludes any additional benefit attributed to produced volumes through third-party trading activities. 33 Exploration 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. 34 Project final investment decisions result in amounts of previously capitalised exploration and evaluation expense (from current and prior years) being transferred to property plant & equipment. This table does not reflect the impact of such transfers. 35 Other primarily incorporates corporate spend including SAP build costs, carbon costs, other investments and other capital expenditure. 36 Represents 80% of the consideration paid in 2024 with the remaining 20% to be paid at project completion. 37 Purchase consideration for Louisiana LNG. 38 Includes seismic and general permit activities and other exploration costs. 39 Well depths are referenced to the rig rotary table. 40 Woodside share reflects the net realised interest for the period. 41 The Wheatstone asset processes gas from several offshore gas fields, including the Julimar and Brunello fields, for which Woodside has 65% participating interest and is the operator. 42 Includes the aggregate Woodside equity domestic gas production from all Western Australian projects. 43 Woodside share reflects the net realised interest for the period. 44 Operations governed by production sharing contracts, Woodside share changes monthly.

This announcement was approved and authorised for release by Woodside’s Disclosure Committee.

View source version on businesswire.com: https://www.businesswire.com/news/home/20250121874664/en/

INVESTORS Marcela Louzada M: +61 456 994 243 E: investor@woodside.com MEDIA Dan Pagoda M: +61 482 675 731 E: dan.pagoda@woodside.com REGISTERED ADDRESS Woodside Energy Group Ltd ACN 004 898 962 Mia Yellagonga 11 Mount Street Perth WA 6000 Australia T: +61 8 9348 4000 www.woodside.com