WDS Woodside Energy Group Ltd

Sangomar fuels record-breaking production

Operations

• Record quarterly production of 53.1 MMboe (577 Mboe/day), up 20% from Q2 2024 due to ramp-up of Sangomar, increased uptime across operated assets including 99.9% LNG reliability at Pluto and increased seasonal domestic gas demand. Full-year production guidance has been narrowed to 189–195 MMboe.
• Quarterly revenue of $3,679 million, up 21% from Q2 2024 primarily due to Sangomar cargo sales and higher average LNG prices.
• Achieved nameplate capacity at Sangomar with gross production rates of 100,000 barrels per day.
• Capitalised on increased gas-hub prices by selling 39% of produced LNG cargoes in the quarter on prices linked to gas hub indices.1 Full year gas hub guidance has been increased to 33–37% of produced LNG.

Projects

• The Scarborough Energy Project was 73% complete at the end of the quarter, with trunkline installation successfully completed in October. The project is on track for first LNG cargo in 2026.2
• The Trion Project was 15% complete at the end of the quarter and is targeting first oil in 2028.
• Completed acquisition of OCI’s Clean Ammonia Project in Beaumont, Texas for an all-cash consideration of approximately $2,350 million, with 80% paid and the remaining 20% to be paid at project completion. The project is targeting first ammonia production from 2025 and lower carbon ammonia from 2026.3

Other

• Completed acquisition of Tellurian and its US Gulf Coast Driftwood LNG development opportunity in October. The project has been renamed Woodside Louisiana LNG.
• Signed a sale and purchase agreement (SPA) with JERA for the supply of approximately 0.4 Mtpa LNG for 10 years.
• Executed 66 PJ of Western Australian gas sales for delivery across 2025 and 2026.
• Successfully completed issuance of $2 billion of senior unsecured bonds to quality debt investors in the US market, with the book peaking at almost four times oversubscribed.

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

Woodside CEO Meg O’Neill said:

“We would like to acknowledge the tragic death in early October of an employee of one of the construction contractors at our Clean Ammonia Project in Beaumont, Texas.

“Safety is our top priority. We are taking steps to understand the circumstances around what occurred and are working closely with local authorities, OCI and the contractor company.

“Our production for the third quarter was a record 53.1 million barrels of oil equivalent. The strong operational performance was underpinned by the accelerated ramp-up of Sangomar and exceptional performance at Pluto LNG and NWS, which recorded 99.9% and 99.2% reliability respectively.

“Our 39% exposure to LNG gas hub indices allowed us to take advantage of increased LNG spot prices in the market over the period, demonstrating the importance of maintaining a balanced and flexible portfolio.

“At Sangomar the 24-well drilling program has been completed and the project has achieved nameplate capacity of 100,000 barrels per day. Commissioning activities continue to progress as planned and start-up of gas and water injection systems is underway.

The Scarborough Energy Project in Western Australia is now 73% complete and remains on target for first LNG cargo in 2026. Installation of the offshore Scarborough gas trunkline was completed in early October.

“At the end of September we completed the acquisition of OCI’s Clean Ammonia Project in Beaumont, Texas. Subsequent to quarter end, we completed the acquisition of Tellurian and its development opportunity, now named Woodside Louisiana LNG.

“The Clean Ammonia Project is expected to produce first ammonia in 2025 and at Woodside Louisiana LNG we are targeting final investment decision (FID) readiness from the first quarter of 2025. These acquisitions expand our diverse, geographically advantaged portfolio and position Woodside to execute our strategy to thrive through the energy transition and deliver long-term value to shareholders.

“Our sale and purchase agreement with JERA for the long-term supply of LNG from Woodside’s global portfolio again evidenced the value Asian customers place on our product.

“Woodside’s commitment to the domestic market was also demonstrated by the execution of gas sales of 66 petajoules (PJ) across 2025 and 2026 in Western Australia. In eastern Australia, to date we have executed sales of 63 PJ across 2025 and 2026 under an ongoing Expression of Interest process, with further sales expected to be completed in the fourth quarter.” 

1 16% of total equity production in the quarter was sold on prices linked to gas hub indices.

2 The completion % excludes the Pluto Train 1 modifications project.

3 Production of lower carbon ammonia is conditional on supply of carbon abated hydrogen and ExxonMobil’s CCS facility becoming operational. See disclaimer and important notices on page 16 for information on “lower carbon ammonia”.

 

Comparative performance at a glance

 

Q3

2024

Q2

2024

Change %

Q3

2023

Change %

YTD

2024

YTD

2023

Change

%

Revenue

$ million

3,679

3,033

21%

3,259

13%

9,681

10,673

(9%)

Production4

MMboe

53.1

44.4

20%

47.8

11%

142.4

139.1

2%

 

Gas

MMscf/d

2,001

1,885

6%

2,001

-

1,939

2,000

(3%)

 

Liquids

Mbbl/d

226

157

44%

169

34%

180

159

13%

 

Total

Mboe/d

577

488

18%

520

11%

520

510

2%

Sales

MMboe

55.8

48.0

16%

53.3

5%

149.7

152.1

(2%)

 

Gas

MMscf/d

2,154

2,103

2%

2,341

(8%)

2,075

2,292

(9%)

 

Liquids

Mbbl/d

228

159

43%

169

35%

182

155

17%

 

Total

Mboe/d

606

528

15%

579

5%

546

557

(2%)

Average realised price

$/boe

65

62

5%

60

8%

63

69

(9%)

Capital expenditure5

$ million

3,033

1,233

146%

1,360

123%

5,445

4,135

32%

 

Capex excl. acquisitions

$ million

1,133

1,233

(8%)

1,360

(17%)

3,545

4,135

(14%)

 

Acquisitions6

$ million

1,900

-

100%

-

100%

1,900

-

100%

Operations

Pluto LNG

• Achieved outstanding quarterly LNG reliability of 99.9%.

North West Shelf (NWS) Project

• Achieved outstanding quarterly LNG reliability of 99.2%.
• Successfully completed planned maintenance offshore at North Rankin Complex and an onshore LNG train at Karratha Gas Plant (KGP), and production has recommenced as planned.
• Continued to pursue opportunities for third party onshore gas processing following announcement of the Western Australian Government’s updated policy allowing onshore gas exports.
• Took FID on the Low-Low Pressure Operation Project at Goodwyn Alpha, aimed at increasing NWS production from the Goodwyn area reservoirs. This project is targeted for start-up in Q2 2027.
• Planning to bring one LNG train offline for retirement in the fourth quarter of 2024.

4 Q3 2024 includes 0.28 MMboe, Q2 2024 includes 0.30 MMboe and Q3 2023 includes 0.26 MMboe primarily from feed gas purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector.

5 Includes capital additions on property plant and equipment, exploration and evaluation capitalised, other corporate spend and investment expenditure on Beaumont Clean Ammonia Project.

6 Acquisition of OCI’s Clean Ammonia Project in Beaumont, Texas.

Bass Strait

• Safely completed the Kipper Compression Project, adding compression facilities on the West Tuna Platform, increasing production potential of existing well stock and enabling development of additional Kipper reserves.
• Continued optimisation of facilities through the Gippsland Asset Streamlining project with closure of the Cobia Platform in September 2024.
• Ethane power generation project successfully started up in September.

Sangomar

• Achieved nameplate capacity of 100,000 barrels per day in July 2024.
• Continued to receive strong interest in Sangomar crude from buyers in Europe and Asia.
• The final Phase 1 well was drilled and completed in the period. The Sangomar drilling campaign is now complete marking the successful drilling and completion of 24 development wells.
• Start-up of gas and water injection systems has commenced and commissioning activities are expected to continue through 2024.

Gulf of Mexico

• Completed a planned shutdown on Shenzi in July 2024 which included integrity inspections and control system improvements.
• Completed a planned three-well intervention campaign on Mad Dog A-Spar.
• In September, Hurricanes Francine and Helene caused deferrals at our operated and non-operated GOM facilities, largely due to availability of third-party infrastructure and planned facility ramp down.

Marketing and Trading

• Signed a long-term LNG SPA with JERA to supply approximately 0.4 million tonnes (six cargoes) of LNG per year over 10 years on a delivered basis, commencing in April 2026. LNG delivered under the SPA will be sourced from volumes across Woodside’s global portfolio.
• Sold 39% of produced LNG at prices linked to gas hub indices in the quarter (36% year to date).7Full year gas hub guidance has been increased to 33–37% of produced LNG.
• Executed 66 PJ of Western Australian gas sales 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.
• Woodside continued its eastern Australian Expression of Interest (EOI) process with executed sales to date already of 63 PJ across 2025 and 2026. The remaining sales under the EOI process are expected to be completed in Q4 2024.

Projects

Scarborough Energy Project

• The Scarborough and Pluto Train 2 project was 73% complete at the end of the quarter.
• 41 of 51 Pluto Train 2 modules have been delivered to site, with 39 modules set in position at the end of the quarter.
• Fabrication of the floating production unit (FPU) hull and topsides progressed, with installation of piping, electrical, and instrumentation packages continuing on the topsides and the hull entering its second dry dock in preparation for FPU integration activities in 2025.
• Trunkline installation was completed subsequent to the quarter.
• The drilling program continued with batch drilling of the development wells ongoing.
• First steel was cut at the module yard on the Pluto Train 1 modifications project and site preparation works at the Pluto LNG facility commenced.
• First LNG cargo is targeted for 2026.

7 16% of total equity production in the quarter was sold on prices linked to gas hub indices (16% of total equity production year to date).

Trion

• The Trion project was 15% complete at the end of the quarter.
• Awarded contracts for the floating, storage and offloading vessel (FSO) bare boat charter, aviation services, and fibre optic trunkline installation.
• Procurement activities continued, including delivery of long lead items to subsea equipment manufacturers.
• Completed the FPU hull 90% model review and initiated FPU pre-construction activities.

Woodside Louisiana LNG (Driftwood LNG)

• Subsequent to the quarter, completed acquisition of Tellurian and its US Gulf Coast Driftwood LNG development opportunity in Calcasieu Parish, Louisiana.
• Woodside acquired all issued and outstanding Tellurian common stock for approximately $900 million cash, or $1.00 per share. The implied enterprise value was approximately $1,200 million.8
• Woodside has renamed the Driftwood LNG development opportunity Woodside Louisiana LNG.
• Woodside is targeting FID readiness from the first quarter of 2025.

Decommissioning

• The Griffin, Stybarrow and Enfield decommissioning campaign continued with ~54 km of flexible flowlines and umbilicals recovered in the quarter, and completion of wellhead severance activities at Enfield.
• The well plug and abandonment campaign at the Stybarrow field is 40% complete, with 4 wells plugged and abandoned to date.
• At Mad Dog in US Gulf of Mexico, operator (BP) completed plug and abandonment of well 869-1.

Exploration and development

Calypso

• Pre-front-end engineering design (FEED) engineering studies continued to mature the technical definition and cost estimate for the deepwater infield host.
• Fiscal and marketing negotiations continued with various counterparties to assess the commercial options to monetise the Calypso resource.

Browse

• Additional information was provided to the WA Environmental Protection Authority to support the final phase of assessment of the Browse to North West Shelf Project environmental referral.
• Engineering studies on Browse to North West Shelf Project continue to optimise the upstream development concept and improve project cost and schedule certainty.

Sunrise

• The Sunrise Joint Venture participants continued negotiations with the Australian and Timor-Leste Governments to progress a new Production Sharing Contract, Petroleum Mining Code and fiscal regime.
• The concept study for the potential development of Greater Sunrise is expected to conclude in Q4 2024.

8 Includes $50 million for Tellurian’s Series C Convertible Preferred equity shares, ~$65 million of net debt, ~$20 million net working capital adjustment, ~$50 million for management and debt change of control costs and ~$135m of interim funding from signing to close. Does not include management construction incentive payment awards. The accounting treatment of the purchase price will be included in Woodside’s 2024 Annual Report and will include share purchase consideration, interim funding and other items.

Exploration

• In Congo, the Niamou Marine-1 (non-operated) well reached total depth in September 2024. The well did not encounter hydrocarbons.
• In September 2024, Woodside was granted Exploration Permit WA-554-P in the Barrow sub-Basin, Western Australia. WA-554-P comprises a total area of 943 km2. Woodside holds a 100% working interest in the permit.
• Subsequent to the period, Woodside acquired a 40% non-operated stake in ENI’s Tiba Block in the Nile Delta, Egypt.

New energy and carbon solutions

Beaumont Clean Ammonia Project

• Completed OCI Clean Ammonia acquisition, comprising 100% of OCI Clean Ammonia Holding B.V., which holds its lower carbon ammonia project in Beaumont, Texas.
• The acquisition was for an all-cash consideration of approximately $2,350 million, inclusive of capital expenditure through completion of phase 1 of the project. OCI is continuing to manage the construction of the project under the Construction Management Agreement.
• Woodside is targeting first ammonia production from 2025 and lower carbon ammonia from 2026 following commencement of CCS operations.9

H2OK

• Secured non-binding offtake term sheets with several customers and continued to advance pricing and volume discussions with additional offtakers.
• Woodside continues to await final guidance for the 45V Clean Hydrogen Production Tax Credit.

Woodside Solar

• Woodside continued working with the Western Australian Government to progress its process to develop common user transmission infrastructure required to support the proposed Woodside Solar project.

Carbon capture and storage (CCS) opportunities

• Woodside was awarded two greenhouse gas assessment permits to progress CCS evaluation work:
  • G-18-AP, offshore Onslow, Western Australia, as part of a joint venture with Chevron Australia New Ventures Pty Ltd; and
  • G-19-AP, off the coast of Victoria, as part of the Gippsland Basin Joint Venture (GBJV).

Corporate activities

London Stock Exchange listing

• Subsequent to the period, Woodside announced it will delist from the London Stock Exchange (LSE). The last day of trading of Woodside shares on the LSE will be 19 November 2024.

Funding

• Woodside successfully raised $2 billion in the US market through a multi-tranche SEC registered bond in September 2024, comprising a $1.25 billion 10-year bond and a $0.75 billion 30-year bond.
• Woodside converted and upsized an existing $800 million revolving facility to a new $1.2 billion 7-year syndicated term loan primarily from Asian and European banks.

9 Production of lower carbon ammonia is conditional on supply of carbon abated hydrogen and ExxonMobil’s CCS facility becoming operational. See disclaimer and important notices on page 18 for information on “lower carbon ammonia”.

Hedging

• Woodside hedged approximately 29.3 MMboe of 2024 oil production at an average price of approximately $75.6 per barrel, with approximately 72% delivered as of 30 September 2024.
• As at 30 September, Woodside had hedged approximately 18.6 MMboe of 2025 production. An additional 11.4 MMboe was subsequently added with the total for 2025 now 30 MMboe at an average price of approximately $78.75.
• 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 88% of volumes for the remainder of 2024, 83% of 2025 and 25% of 2026 volumes have been hedged.
• The year-to-date realised value of all hedged positions for as of 30 September 2024 is a pre-tax expense of approximately $70 million, with $195 million related to oil price hedges offset by $88 million profit related to Corpus Christi hedges and $37 million related to other hedge positions. Hedging losses will be included in “other expenses” in the full-year financial statements.

Climate and sustainability

• Woodside released its 2023 Reconciliation Action Plan 2021-2025 (RAP) Report. The report reflects Woodside’s progress against the four pillars outlined in the RAP including Respect for Culture and Heritage, Capability and Capacity, Economic Participation, and Stronger Communities.
• Subsequent to the period Woodside signed a memorandum of understanding (MOU) with the Japan Organisation for Metals and Energy Security (JOGMEC) regarding collaboration on methane emissions management.

Upcoming events 2024 - 2025

November 2024

6-7

Australia investor site visit

January 2025

22

Q4 2024 Report

2024 full-year guidance

 

 

Prior

Current

Production

MMboe

185 – 195

(505 – 533 Mboe/day)

189 – 195

(516 – 533 Mboe/day)

Capital expenditure10

$ billion

5.0 – 5.5

4.8 – 5.2

Gas hub exposure11

% of produced LNG

26 – 33

33 – 37

10 Capital expenditure includes the following participating interests; Sangomar (82%); Scarborough (90% following completion of the transaction with LNG Japan in March 2024 and 74.9% following completion of the transaction with JERA, expected in the second half of 2024), Pluto Train 2 (51%) and Trion (60%). Trion capital expenditure includes Pemex carry. This guidance assumes no change to these participating interests in 2024. This excludes the impact of any future asset sell-downs, acquisitions or other changes in equity.

11 Gas hub indices include Japan Korea Marker (JKM), TTF and National Balancing Point (NBP). It excludes HH.

Production summary

 

 

Q3

2024

Q2

2024

Q3

2023

YTD

2024

YTD

2023

Gas

MMscf/d

2,001

1,885

2,001

1,939

2,000

Liquids

Mbbl/d

226

157

169

180

159

Total

Mboe/d

577

488

520

520

510

 

 

Q3

2024

Q2

2024

Q3

2023

YTD

2024

YTD

2023

AUSTRALIA

 

LNG

 

North West Shelf

Mboe

7,029

7,088

6,590

22,309

25,009

Pluto12

Mboe

12,007

11,726

12,261

35,487

33,180

Wheatstone

Mboe

2,565

1,959

2,610

6,881

7,654

Total

Mboe

21,601

20,773

21,461

64,677

65,843

 

 

 

 

 

 

Pipeline gas

 

 

 

 

 

Bass Strait

Mboe

4,069

3,410

4,591

9,838

11,894

Other13

Mboe

4,016

3,848

3,472

11,142

9,589

Total

Mboe

8,085

7,258

8,063

20,980

21,483

 

 

 

 

 

 

Crude oil and condensate

 

 

 

 

 

North West Shelf

Mbbl

1,265

1,260

1,278

3,937

4,508

Pluto12

Mbbl

966

933

976

2,830

2,636

Wheatstone

Mbbl

474

380

477

1,316

1,310

Bass Strait

Mbbl

701

503

982

1,696

2,663

Macedon & Pyrenees

Mbbl

633

107

688

849

2,078

Ngujima-Yin

Mbbl

1,231

974

1,140

3,091

2,009

Okha

Mbbl

615

491

608

1,572

1,460

Total

Mboe

5,885

4,648

6,149

15,291

16,664

 

 

 

 

 

 

NGL

 

 

 

 

 

North West Shelf

Mbbl

288

279

276

857

907

Pluto12

Mbbl

55

59

53

168

148

Bass Strait

Mbbl

1,152

941

1,380

2,925

3,294

Total

Mboe

1,495

1,279

1,709

3,950

4,349

 

 

 

 

 

 

 

Total Australia14

Mboe

37,066

33,958

37,382

104,898

108,339

Mboe/d

403

373

406

383

397

12 Q3 2024 includes 1.89 MMboe of LNG, 0.08 MMboe of condensate and 0.05 MMboe of NGL, Q2 2024 includes 2.18 MMboe of LNG, 0.10 MMboe of condensate and 0.06 MMboe of NGL and Q3 2023 includes 2.07 MMboe of LNG and 0.08 MMboe of condensate and 0.05 MMboe of NGL processed at the Karratha Gas Plant (KGP) through the Pluto-KGP Interconnector.

13 Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.

14 Q3 2024 includes 0.28 MMboe, Q2 2024 includes 0.30 MMboe and Q3 2023 includes 0.26 MMboe primarily from feed gas purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector.

 

 

 

Q3

2024

Q2

2024

Q3

2023

YTD

2024

YTD

2023

INTERNATIONAL

 

 

 

 

 

 

Pipeline gas

 

Gulf of Mexico

Mboe

327

324

350

1,011

1,029

Trinidad & Tobago

Mboe

2,289

1,736

2,413

6,528

7,372

Other15

Mboe

-

-

17

-

47

Total

Mboe

2,616

2,060

2,780

7,539

8,448

 

 

 

 

 

 

 

Crude oil and condensate

 

 

 

 

 

 

Atlantis

Mbbl

2,351

2,019

2,714

6,811

8,202

Mad Dog

Mbbl

2,363

2,944

2,188

8,072

4,754

Shenzi

Mbbl

2,047

2,333

2,158

6,785

7,353

Trinidad & Tobago

Mbbl

143

94

201

363

792

Sangomar

Mbbl

5,902

540

-

6,442

-

Other15

Mbbl

81

81

36

243

156

Total

Mboe

12,887

8,011

7,297

28,716

21,257

 

 

 

 

 

 

 

NGL

 

 

 

 

 

 

Gulf of Mexico

Mbbl

515

355

362

1,263

1,043

Other15

Mbbl

-

-

10

-

27

Total

Mboe

515

355

372

1,263

1,070

 

 

 

 

 

 

 

Total International

Mboe

16,018

10,426

10,449

37,518

30,775

Mboe/d

174

115

114

137

113

 

 

 

 

 

 

 

Total production

Mboe

53,084

44,384

47,831

142,416

139,114

Mboe/d

577

488

520

520

510

15 Overriding royalty interests held in the GoM for several producing wells.

Product sales

 

 

Q3

2024

Q2

2024

Q3

2023

YTD

2024

YTD

2023

Gas

MMscf/d

2,154

2,103

2,341

2,075

2,292

Liquids

Mbbl/d

228

159

169

182

155

Total

Mboe/d

606

528

579

546

557

 

 

Q3

2024

Q2

2024

Q3

2023

YTD

2024

YTD

2023

AUSTRALIA

 

LNG

 

North West Shelf

Mboe

7,353

7,081

7,639

22,442

27,206

Pluto

Mboe

12,014

12,749

12,622

35,276

33,524

Wheatstone16

Mboe

3,048

2,264

2,541

7,901

7,203

Total

Mboe

22,415

22,094

22,802

65,619

67,933

 

 

 

 

 

 

Pipeline gas

 

 

 

 

 

Bass Strait

Mboe

4,163

3,508

4,506

10,241

11,701

Other17

Mboe

3,816

3,435

3,243

10,145

9,222

Total

Mboe

7,979

6,943

7,749

20,386

20,923

 

 

 

 

 

 

Crude oil and condensate

 

 

 

 

 

North West Shelf18

Mbbl

1,253

1,904

1,471

4,371

4,155

Pluto

Mbbl

858

1,283

1,228

2,781

2,456

Wheatstone

Mbbl

360

666

689

1,355

1,348

Bass Strait

Mbbl

662

271

1,407

1,530

2,524

Ngujima-Yin

Mbbl

1,082

1,018

708

3,099

1,849

Okha

Mbbl

618

572

1,297

1,808

1,950

Macedon & Pyrenees

Mbbl

498

-

1

994

1,551

Total

Mboe

5,331

5,714

6,801

15,938

15,833

 

 

 

 

 

 

NGL

 

 

 

 

 

North West Shelf

Mbbl

249

266

263

770

688

Pluto

Mbbl

52

49

32

156

287

Bass Strait

Mbbl

1,142

361

959

2,288

2,971

Total

Mboe

1,443

676

1,254

3,214

3,946

 

 

 

 

 

 

Total Australia

Mboe

37,168

35,427

38,606

105,157

108,635

Mboe/d

404

389

420

384

398

16 Includes periodic adjustments reflecting the arrangements governing Wheatstone LNG sales of 0.29 MMboe in Q3 2024, 0.19 MMboe in Q2 2024 and 0.16 MMboe in Q3 2023.

17 Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.

18 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.

 

Q3

2024

Q2

2024

Q3

2023

YTD

2024

YTD

2023

INTERNATIONAL

 

 

 

 

 

 

Pipeline gas

 

 

 

 

 

 

Gulf of Mexico

Mboe

286

336

321

908

1,005

Trinidad & Tobago

Mboe

2,004

1,606

2,574

6,067

7,569

Other19

Mboe

2

5

7

13

20

Total

Mboe

2,292

1,947

2,902

6,988

8,594

 

 

 

 

 

 

 

Crude oil and condensate

 

 

 

 

 

 

Atlantis

Mbbl

2,436

2,013

2,442

6,875

7,820

Mad Dog

Mbbl

2,489

3,043

2,041

8,158

4,610

Shenzi

Mbbl

2,032

2,430

2,123

6,814

7,448

Trinidad & Tobago

Mbbl

221

19

242

292

903

Sangomar

Mbbl

6,070

-

-

6,070

-

Other19

Mbbl

45

59

61

164

189

Total

Mboe

13,293

7,564

6,909

28,373

20,970

 

 

 

 

 

 

 

NGL

 

 

 

 

 

 

Gulf of Mexico

Mbbl

388

454

379

1,255

1,084

Other19

Mbbl

1

3

4

7

11

Total

Mboe

389

457

383

1,262

1,095

 

 

 

 

 

 

 

Total International

Mboe

15,974

9,968

10,194

36,623

30,659

Mboe/d

174

110

111

134

112

 

 

 

 

 

 

 

MARKETING20

 

 

 

 

 

 

LNG

Mboe

2,077

2,593

4,329

6,756

12,344

Liquids21

Mboe

555

37

169

1,163

429

Total

Mboe

2,632

2,630

4,498

7,919

12,773

 

 

 

 

 

 

 

Total Marketing

Mboe

2,632

2,630

4,498

7,919

12,773

 

 

 

 

 

 

 

Total sales

Mboe

55,774

48,025

53,298

149,699

152,067

Mboe/d

606

528

579

546

557

19 Includes periodic adjustments reflecting the arrangements governing Wheatstone LNG sales of 0.29 MMboe in Q3 2024, 0.19 MMboe in Q2 2024 and 0.16 MMboe in Q3 2023.

20 Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.

21 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.

Revenue

 

Q3

2024

Q2

2024

Q3

2023

YTD

2024

YTD

2023

AUSTRALIA

North West Shelf

520

524

575

1,636

2,512

Pluto

920

891

923

2,556

2,778

Wheatstone22

237

202

246

662

774

Bass Strait

344

247

379

814

918

Macedon

48

48

41

147

145

Ngujima-Yin

94

91

64

277

164

Okha

51

46

103

147

159

Pyrenees

44

-

-

88

139

 

 

 

 

 

 

INTERNATIONAL

 

 

 

 

 

Atlantis

194

168

209

558

611

Mad Dog

192

249

170

645

354

Shenzi

160

205

178

555

577

Trinidad & Tobago23

63

38

17

162

265

Sangomar

464

-

-

464

-

Other24

3

5

5

13

14

 

 

 

 

 

 

Marketing revenue25

285

265

298

777

1,121

 

 

 

 

 

 

Total sales revenue26

3,619

2,979

3,208

9,501

10,531

 

 

 

 

 

 

Processing revenue

54

52

50

167

135

Shipping and other revenue

6

2

1

13

7

 

 

 

 

 

 

Total revenue

3,679

3,033

3,259

9,681

10,673

22 Q3 2024 includes -$28 million, Q2 2024 includes -$10 million and Q3 2023 includes $11 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.

23 Includes the impact of periodic adjustments related to the production sharing contract (PSC).

24 Overriding royalty interests held in the GoM for several producing wells.

25 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.

26 Total sales revenue excludes all hedging impacts.

Realised prices

 

Units

Q3

2024

Q2

2024

Q3

2023

Units

Q3

2024

Q2

2024

Q3

2023

LNG produced27

$/MMBtu

10.8

9.6

10.3

$/boe

68

60

65

LNG traded28

$/MMBtu

11.2

9.1

8.2

$/boe

71

58

52

Pipeline gas

 

 

 

 

$/boe

38

38

28

Oil and condensate

$/bbl

78

83

82

$/boe

78

83

82

NGL

$/bbl

48

44

45

$/boe

48

44

45

Liquids traded28

$/bbl

60

79

72

$/boe

60

79

72

 

 

 

 

 

 

 

 

Average realised price for pipeline gas:

 

 

 

 

 

 

 

 

Western Australia

 

 

 

 

A$/GJ

6.5

6.5

6.1

 

East coast Australia

 

 

 

 

A$/GJ

14.2

14.3

12.3

 

International

 

 

 

 

$/Mcf

4.3

3.9

3.8

Average realised price

 

$/boe

65

62

60

 

 

 

 

 

 

 

 

 

Dated Brent

 

$/bbl

80

85

87

JCC (lagged three months)

 

$/bbl

88

84

84

WTI

 

 

 

 

$/bbl

75

81

82

JKM

 

 

 

 

$/MMBtu

12.4

9.6

10.9

TTF

 

 

 

 

$/MMBtu

11.2

9.2

10.3

Average realised price increased 5% from the prior quarter reflecting higher JKM, JCC and TTF.

27 Realised prices include the impact of periodic adjustments reflecting the arrangements governing Wheatstone LNG sales.

28 Excludes any additional benefit attributed to produced volumes through third-party trading activities.

Capital expenditure (US$ million)

 

Q3

2024

Q2

2024

Q3

2023

YTD

2024

YTD

2023

Exploration and evaluation capitalised29,30

6

38

3

82

132

Property plant and equipment

1,076

1,135

1,313

3,301

3,821

Other31

51

60

44

162

182

Sub Total (excluding acquisitions)

1,133

1,233

1,360

3,545

4,135

Acquisitions

1,900

-

-

1,900

-

Total

3,033

1,233

1,360

5,445

4,135

 

Q3

2024

Q2

2024

Q3

2023

YTD

2024

YTD

2023

Sangomar

73

206

257

489

808

Scarborough

438

563

613

1,575

1,817

Trion

225

137

111

459

119

Beaumont Clean Ammonia Project

1,900

-

-

1,900

-

Other

397

327

379

1,022

1,391

Total

3,033

1,233

1,360

5,445

4,135

Other expenditure (US$ million)

Q3

2024

Q2

2024

Q3

2023

YTD

2024

YTD

2023

Exploration and evaluation expensed32

90

46

123

190

256

Permit amortisation

2

3

3

8

7

Total

92

49

126

198

263

Trading costs

132

128

265

405

887

29 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.

30 Project final investment decisions result in amounts of previously capitalised exploration and evaluation expense (from current and prior years) being transferred to oil and gas properties. This table does not reflect the impact of such transfers.

31 Other primarily incorporates corporate spend including SAP build costs, carbon costs and other investments.

32 Includes seismic and general permit activities and other exploration costs.

Exploration or appraisal wells drilled

Region

Permit Area

Well

Target

Interest (%)

Spud Date

Water depth (m)

Actual well depth (m)33

Remarks

Congo

Marine XX

Niamou Marine 1

Oil

22.5% Non-Operator

24 May 2024

2,094

6,928

Drilling complete

Permits and licences

Key changes to permit and licence holdings during the quarter ended 30 September 2024 are noted below.

Region

Permits or licence areas

Change in interest (%)

Current interest (%)

Remarks

Australia

WA-554-P

100%

100%

Licence entry

Gulf of Mexico

GB 729, GB 772, GB 773

(40%)

0

Licence expiry

Egypt – Nile Delta34

Tiba Block

40%

40%

Licence entry

 

33 Well depths are referenced to the rig rotary table.

34 Subsequent to the period

Production rates

Average daily production rates (100% project) for the quarter ended 30 September 2024:

 

Woodside share35

Production rate (100% project, Mboe/d)

Remarks

 

Sept

2024

June

2024

 

AUSTRALIA

 

 

 

 

NWS Project

 

 

 

 

LNG

29.58%

259

256

Crude oil and condensate

29.71%

46

46

NGL

29.71%

10

10

 

 

 

 

 

Pluto LNG

 

 

 

 

LNG

90.00%

122

116

Production was higher following completion of planned maintenance activities in Q2.

Crude oil and condensate

90.00%

10

10

 

 

 

 

 

Pluto-KGP Interconnector

 

 

 

 

LNG

100.00%

21

24

 

Crude oil and condensate

100.00%

1

1

NGL

100.00%

1

1

 

 

 

 

 

Wheatstone36

 

 

 

 

LNG

12.02%

232

212

Production was higher due to improved reliability.

Crude oil and condensate

14.68%

33

30

 

 

 

 

 

Bass Strait

 

 

 

 

Pipeline gas

43.83%

102

86

Production was higher due to increased seasonal domestic gas demand.

Crude oil and condensate

46.73%

16

12

NGL

47.40%

26

23

 

 

 

 

 

Australia Oil

 

 

 

 

Ngujima-Yin

60.00%

22

18

Production at Ngujima-Yin and Okha was higher due to improved reliability and production optimisation.

Okha

50.00%

13

11

Pyrenees

63.48%

11

2

Production at Pyrenees was higher following completion of planned turnaround in Q2.

 

 

 

 

 

Other

 

 

 

 

Pipeline gas37

 

44

42

 

 

35 Woodside share reflects the net realised interest for the period.

36 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.

37 Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.

 

 

Woodside share38

Production rate (100% project, Mboe/d)

Remarks

 

 

Sept

2024

June

2024

 

INTERNATIONAL

 

 

 

 

Atlantis

 

 

 

 

Crude oil and condensate

38.50%

66

58

Production was higher following completion of planned turnaround activities in Q2, partially offset by weather.

NGL

38.50%

5

4

Pipeline Gas

38.50%

7

5

 

 

 

 

 

Mad Dog

 

 

 

 

Crude oil and condensate

20.86%

123

155

Production was lower due to planned interventions and weather.

NGL

20.86%

7

5

Pipeline Gas

20.86%

2

3

 

 

 

 

 

Shenzi

 

 

 

 

Crude oil and condensate

65.02%

34

39

Production was lower due to planned well intervention, unplanned downtime, and weather.

NGL

64.69%

3

2

Pipeline Gas

63.93%

1

1

 

 

 

 

Trinidad & Tobago

 

 

 

 

Crude oil and condensate

57.49%39

3

2

Production was higher following completion of planned maintenance activities in Q2.

Pipeline gas

50.31%39

49

39

 

 

 

 

 

Sangomar

 

 

 

 

Crude Oil

78.74%39

81

8

Production was higher due to continued ramp-up and commissioning of the field.

38 Woodside share reflects the net realised interest for the period.

39 Operations governed by production sharing contracts, Woodside share may change monthly.

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, statements regarding long-term demand for Woodside’s products, 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, and expectations regarding the achievement of Woodside’s net equity Scope 1 and 2 greenhouse gas emissions reduction and new energy investment targets and other climate and sustainability goals.

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, 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 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, 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 third parties, project delay or advancement, regulatory approvals, the impact of armed conflict and political instability (such as the ongoing conflict 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, 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 and joint ventures, including difficulties integrating 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 the London Stock 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.

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 of 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.

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.

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 30 September 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

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/20241015929378/en/

INVESTORS Marcela Louzada M: +61 456 994 243 E: investor@woodside.com

MEDIA Christine Forster M: +61 484 112 469 E: christine.forster@woodside.com