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 October 2024

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 of principal 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): ☐

 

 

 



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: October 16, 2024

 

WOODSIDE ENERGY GROUP LTD
By:  

/s/ Damien Gare

 

Damien Gare

Corporate Secretary

Exhibit 99.1

THIRD QUARTER REPORT FOR PERIOD ENDED 30 SEPTEMBER 2024

LOGO

ASX: WDS | NYSE: WDS | LSE: WDS

Wednesday, 16 October 2024

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 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.

 

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”.

 

 

1        Third quarter report for period ended 30 September 2024    LOGO
 


“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.”

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.

 

 

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.

 

 

2        Third quarter report for period ended 30 September 2024    LOGO
 


   

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.

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).7 Full 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.

 

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).

 

 

3        Third quarter report for period ended 30 September 2024    LOGO
 


   

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.

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.

 

 

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.

 

 

4        Third quarter report for period ended 30 September 2024    LOGO
 


   

The concept study for the potential development of Greater Sunrise is expected to conclude in Q4 2024.

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”.

 

 

5        Third quarter report for period ended 30 September 2024    LOGO
 


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.

 

 

6        Third quarter report for period ended 30 September 2024    LOGO
 


Contacts:      
INVESTORS    MEDIA    REGISTERED ADDRESS
      Woodside Energy Group Ltd.
      ACN 004 898 962
Marcela Louzada    Christine Forster    Mia Yellagonga
M: +61 456 994 243    M: +61 484 112 469    11 Mount Street
E: investor@woodside.com    E: christine.forster@woodside.com    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.

 

 

7        Third quarter report for period ended 30 September 2024    LOGO
 


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.

 

 

8        Third quarter report for period ended 30 September 2024    LOGO
 


            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.

 

 

9        Third quarter report for period ended 30 September 2024    LOGO
 


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.

 

 

10        Third quarter report for period ended 30 September 2024    LOGO
 


            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 

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

20 

Purchased volumes sourced from third parties.

21 

Includes reclassification of purchased condensate volumes from NWS JV Participants of 0.16 MMboe in Q3 2023 and 0.26 MMboe in Q2 2023.

 

 

11        Third quarter report for period ended 30 September 2024    LOGO
 


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.

 

 

12        Third quarter report for period ended 30 September 2024    LOGO
 


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.

 

 

13        Third quarter report for period ended 30 September 2024    LOGO
 


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.

 

 

14        Third quarter report for period ended 30 September 2024    LOGO
 


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

 

 

15        Third quarter report for period ended 30 September 2024    LOGO
 


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.

 

 

16        Third quarter report for period ended 30 September 2024    LOGO
 


     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.

 

 

17        Third quarter report for period ended 30 September 2024    LOGO
 


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.

 

 

18        Third quarter report for period ended 30 September 2024    LOGO
 


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

 

 

19        Third quarter report for period ended 30 September 2024    LOGO
 

Exhibit 99.2

 

LOGO

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

ASX: WDS

NYSE: WDS

LSE: WDS

Announcement

Wednesday, 16 October 2024

WOODSIDE TO DELIST FROM THE LONDON STOCK EXCHANGE

Woodside has reviewed its current listing structure and decided to delist from the London Stock Exchange (LSE). Woodside shares represented by depositary interests account for approximately 1% of Woodside’s issued share capital. Trading volumes of Woodside shares on the LSE are low and delisting from the LSE will reduce Woodside’s administration costs.

Woodside has applied to the UK Financial Conduct Authority (FCA) and the LSE to cancel the admission of Woodside shares to listing in the International Commercial Companies Secondary Listing category of the Official List of the FCA and trading under the ticker “WDS” on the Main Market for listed securities of the LSE.

In accordance with UK Listing Rule 21.2.17, Woodside is required to give at least 20 business days’ notice of the intended cancellation of the listing of its shares. It is expected that the admission of Woodside’s shares to the International Commercial Companies Secondary Listing category of the Official List and to trading on the LSE’s Main Market for listed securities will be cancelled with effect from 08:00 (GMT) on 20 November 2024. The last day of trading of Woodside shares on the LSE will be 19 November 2024.

Woodside’s primary listing on the Australian Securities Exchange (ASX) and its American Depositary Receipts (ADR) program on the New York Stock Exchange (NYSE) will not be affected by the delisting of Woodside shares from the LSE.

 

Page 1 of 2


Further information

Information on the delisting and termination of depositary arrangements and the options available to depositary interest holders, including how to sell their depositary interests, will be sent to depositary interest holders from Computershare. For further information on the transfer of LSE depositary interest holdings to ASX shares or for queries related to sale options, please contact:

Computershare Investor Services PLC

  Telephone:

+ 44 (0)370 703 6075

  Email:

WebCorres@computershare.co.uk

Depositary interest holders who receive Woodside shares upon termination of Woodside’s depositary interest arrangements and who wish to hold ADRs listed on the NYSE should contact Citibank N.A., the depositary for Woodside’s ADR program, following receipt of their ASX-listed Woodside shares:

Citibank Shareholder Services

  Telephone:

+1 781 575 4555

  Email:

citibank@shareholders-online.com

For further information refer to www.woodside.com/investors/lse-delisting.

 

 

 

Contacts:

  

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

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

 

Page 2 of 2


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