Woodside Energy Group Ltd 6-K, filed Aug 22, 2023
Woodside Energy Group Ltd (WDS)
About this 6-K
Woodside Energy Group Ltd filed this 6-K on August 22, 2023.
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 August 2023
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): ☐
INCORPORATION BY REFERENCE
Exhibit 99.1 to this report on Form 6-K (excluding the “Auditor’s Independence Declaration to the Directors of Woodside Energy Group” on page 18 of such Exhibit and the “Independent auditor’s review report to the members of Woodside Energy Group Ltd” on pages 43 and 44 of such Exhibit) shall be deemed to be incorporated by reference into the Registration Statements on Form S-8 (File Nos. 333-270076, 333-267432 and 333-265606) of Woodside Energy Group Ltd and to be a part thereof from the date of this report, to the extent not superseded by documents or reports subsequently filed or furnished.
Exhibit 99.2 to this report on Form 6-K is furnished, not filed, and shall not be deemed to be incorporated by reference into any Registration Statement filed by Woodside Energy Group Ltd under the Securities Act of 1933.
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: August 22, 2023
| WOODSIDE ENERGY GROUP LTD | ||
| By: | /s/ Warren Baillie | |
| Warren Baillie | ||
| Corporate Secretary | ||
Exhibit 99.1
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
Tuesday, 22 August 2023
HALF-YEAR REPORT FOR PERIOD ENDED 30 JUNE 2023
Safety performance
| • | There was a fatality in June 2023 at the North Rankin Complex. Woodside’s investigation is ongoing. Immediate actions have been implemented and preliminary lessons shared with industry |
Financial highlights for H1 2023
| • | Record H1 net profit after tax of US$1,740 million |
| • | Underlying net profit after tax of US$1,896 million |
| • | Positive free cash flow of US$294 million |
| • | Record Australian tax and royalty payments of A$3,654 million |
| • | Liquidity of US$7,509 million |
| • | Declared an interim dividend of 80 US cents per share, representing a half-year annualised dividend yield of 6.9%1 |
Operational highlights
| • | Delivered record H1 production of 91.3 MMboe |
| • | Achieved first production at the Mad Dog Phase 2 Argos platform in April 2023 |
| • | Completed major turnaround at Pluto LNG on schedule |
Business highlights
| • | The Scarborough development was 38% complete; the floating production unit (FPU) topsides and pipeline fabrication and Pluto Train 2 module fabrication and foundation site works progressed |
| • | Agreed to sell a 10% interest in the Scarborough Joint Venture to LJ Scarborough Pty Ltd (LNG Japan) and established a broader strategic relationship which includes potential LNG offtake and collaboration on global opportunities in new energy2 |
| • | The Sangomar project was 88% complete; 12 of 23 wells were drilled and completed and the floating production storage and offloading (FPSO) topsides integration and pre-commissioning works continued in Singapore |
| • | Approved a final investment decision (FID) on the Trion project. The development remains subject to regulatory approval of the field development plan (FDP) |
| • | Approved a FID on the Julimar-Brunello Phase 3 project |
| 1 | Calculated based on Woodside’s closing share price on 30 June 2023 of A$34.44 and a US$:A$ exchange rate of 0.67. |
| 2 | Announced 8 August 2023. LJ Scarborough Pty Ltd is currently a wholly owned subsidiary of LNG Japan Corporation, which is a 50:50 joint venture between Sumitomo Corporation and Sojitz Corporation. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 1 |
New energy & carbon highlights
| • | Progressed key project activities for H2OK to support targeted FID readiness in 2023 |
| • | Progressed development of the solar generation, battery energy storage and transmission infrastructure required for the Woodside Solar project in support of targeted FID readiness in 2023 |
| • | Awarded contract for the engineering and fabrication of the hydrogen production equipment for Hydrogen Refueller @H2Perth |
| • | Progressed front-end engineering design (FEED) work on Phase 1 of the South East Australia Carbon Capture and Storage (SEA CCS) project |
Summary
Woodside recorded a half-year net profit after tax (NPAT) of US$1,740 million. Underlying NPAT was US$1,896 million, up 4% on the corresponding period in 2022, reflecting a full period of results with Woodside’s expanded operations portfolio. Operating revenue rose 27% period-on-period to US$7,400 million.
The Directors have declared an interim dividend of 80 US cents per share (cps), representing an approximately 80% payout of underlying NPAT.
Woodside CEO Meg O’Neill said the tragic death of a contractor employee at the North Rankin Complex in early June overshadowed a strong financial and underlying operational performance in the first half of the year.
“The loss of our colleague was a tragedy for his family and friends and has had an emotional impact on everyone at Woodside. Investigations into the incident by Western Australian Police and the National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA) are ongoing, as are Woodside’s internal investigations.
“We have implemented changes to our operational practices based on the preliminary findings of those investigations and shared our learnings with the broader industry via the Safer Together collaboration hub.
“Woodside’s safety performance over the past two years has been below the standard we set for ourselves. We know we must do better and are resolved to strive for a return to leading safety performance.
“Our strong financial performance and our focus on disciplined capital management has enabled us to maintain our interim dividend payout ratio through the cycle.
“Woodside’s gearing remained low at 8.2% at the end of the first half. Our active management of the debt portfolio positions Woodside’s balance sheet well as we invest in future production.
“Woodside also continues to make a significant contribution to the economic prosperity of the communities where we operate. Woodside’s total tax and royalty payments to state and federal governments in Australia in the first half was A$3,654 million.
“Production for the first half was a record at 91.3 million barrels of oil equivalent. The Pluto LNG facility delivered an outstanding 99.9% reliability rate in the five months prior to the planned maintenance turnaround, which was completed on schedule.
“First production was achieved at the Argos platform at Mad Dog Phase 2 in the Gulf of Mexico and we expect output from the facility to ramp up over the remainder of the year.
“During the half a successful appraisal well was drilled in the southwest portion of the Mad Dog field in the Gulf of Mexico and a multi well tie back to Argos is being evaluated.
“In June, Woodside took a FID on the Trion oil development offshore Mexico. The development leverages our proven expertise in deepwater project execution and is expected to deliver strong returns to Woodside shareholders as well as economic and social benefits to Mexico.
“Following FID, Woodside executed a contract with South Korea’s Hyundai Heavy Industries for the construction of the Trion floating production unit. We are looking forward to the approval of the Trion field development plan, expected to be announced by the Mexican regulator in the second half of the year.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 2 |
“We also took FID during the period at Julimar-Brunello Phase 3, a new source of gas for the non-operated Wheatstone facility in Western Australia.
“Work on the Scarborough and Pluto Train 2 project progressed well during the first half. Following acceptance of the Scarborough Trunkline Installation (State Waters) Environmental Plan in April, shore crossing preparations at Pluto commenced and are now nearing completion.
“Two significant milestones were achieved for Scarborough subsequent to the end of the half, with NOPSEMA approving the Environmental Plan for the marine seismic survey and the announcement of the sale of a 10% interest in the offshore joint venture to LNG Japan. The new strategic relationship with LNG Japan also includes the potential for LNG offtake and collaboration on opportunities in new energy.
“While identification of the need for remedial work on the Sangomar floating production and offloading facility was disappointing, we are confident that undertaking the rectifications in the shipyard in Singapore will facilitate a safe and efficient start-up to allow first oil in mid-2024.
“Progress has also been made on our proposed new energy projects. Woodside is actively marketing hydrogen offtake from our proposed H2OK liquid hydrogen project in Oklahoma, in support of our target of being ready to take a FID before year-end.
“In Australia we are aiming to be ready to take FID in the second half of 2023 on the Woodside Solar project, which is expected to supply around 50 MW of energy to Pluto LNG.
“During the half Woodside demonstrated its commitment to providing energy security to Australia’s domestic gas markets, executing several agreements for the total supply of around 120 petajoules of pipeline gas to retailers and industrial users in both the eastern states and Western Australia. Delivery of this gas is expected to take place over the period from end-2023 to 2026,” she said.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 3 |
Financial summary
Key metrics
| H1 2023 |
H1 20223 |
Change % |
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| Operating revenue |
$ | million | 7,400 | 5,810 | 27 | % | ||||||||||
| EBITDA excluding impairment4 |
$ | million | 4,888 | 3,971 | 23 | % | ||||||||||
| EBIT4 |
$ | million | 2,791 | 2,982 | (6 | %) | ||||||||||
| Net profit after tax (NPAT)5,6 |
$ | million | 1,740 | 1,640 | 6 | % | ||||||||||
| Underlying NPAT4 |
$ | million | 1,896 | 1,819 | 4 | % | ||||||||||
| Net cash from operating activities7 |
$ | million | 2,931 | 2,506 | 17 | % | ||||||||||
| Investment expenditure4,8,9 |
$ | million | 2,818 | 1,550 | 82 | % | ||||||||||
| Capital expenditure4,8,10 |
$ | million | 2,631 | 1,509 | 74 | % | ||||||||||
| Exploration expenditure4,9 |
$ | million | 187 | 41 | 356 | % | ||||||||||
| Free cash flow4,7,11 |
$ | million | 294 | 2,551 | (88 | %) | ||||||||||
| Dividends distributed |
$ | million | 1,519 | 1,018 | 49 | % | ||||||||||
| Interim dividend declared |
US cps | 80 | 109 | (27 | %) | |||||||||||
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| Key ratios |
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| Earnings |
US cps | 91.7 | 145.5 | (37 | %) | |||||||||||
| Gearing4 |
% | 8.2 | 6.8 | 21 | % | |||||||||||
| Production12 |
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| Gas |
MMboe | 63.5 | 41.9 | 52 | % | |||||||||||
| Liquids |
MMboe | 27.8 | 13.0 | 114 | % | |||||||||||
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| Total |
MMboe | 91.3 | 54.9 | 66 | % | |||||||||||
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| Gas |
MMboe | 72.0 | 47.8 | 51 | % | |||||||||||
| Liquids |
MMboe | 26.8 | 11.8 | 127 | % | |||||||||||
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| Total |
MMboe | 98.8 | 59.6 | 66 | % | |||||||||||
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Appendix 4D
Results for announcement to the market
More information is available on page 45
| US$ million |
||||||||||||||||
| Revenue from ordinary activities |
Increased | 27 | %13 | to | 7,400 | |||||||||||
| Profit from ordinary activities after tax attributable to members |
Increased | 6 | %13 | to | 1,740 | |||||||||||
| Net profit for the period attributable to members |
Increased | 6 | %13 | to | 1,740 | |||||||||||
| Interim dividend – fully franked |
80 US cps H1 2023 | |||||||||||||||
| Record date for determining entitlements to the dividend |
1 September 2023 | |||||||||||||||
| 3 | Throughout this report, H1 2022 reflects the performance of the interests acquired as part of the merger with BHP’s Petroleum business from 1 June 2022. |
| 4 | This is an alternative performance measure (APM) which is a non-IFRS measure that is unaudited. Woodside believes this non-IFRS measure provides useful performance information, however it should not be considered as an indication of, or as a substitute for, statutory measures as an indicator of actual operating performance (such as net profit after tax or net cash from operating activities) or any other measure of financial performance or position presented in accordance with IFRS. Refer to Alternative Performance Measures for a reconciliation for these measures to Woodside’s financial statements on pages 51-52 and Non-IFRS Measures on page 56 for more information about non-IFRS measures. |
| 5 | Net profit after tax attributable to equity holders of the parent. |
| 6 | The global operations effective income tax rate (EITR) is 13.9%. As a result of the final investment decision to develop the Trion resource in 2023, the Group has recognised deferred tax assets of $319 million, resulting in a reduction of the global EITR from 29.6% to 13.9%. The EITR is calculated as the Group’s income tax expense divided by profit before income tax. EITR for H1 2022 is 32.9%. |
| 7 | H1 2022 comparative has been restated due to the reclassification of purchases of shares and payments relating to employee share plans from cash flows from financing activities to cash flows from operating activities. |
| 8 | Excludes the effect of Global Infrastructure Partners’ (GIP) additional contribution to Pluto Train 2. |
| 9 | Excludes prior period expenditure written off and permit amortisation and includes evaluation expense. |
| 10 | Excludes exploration capitalised. |
| 11 | Cash flow from operating activities less cash flow from investing activities. Free cash flow of $294 million includes the impact of collateral receipts of $332 million against hedging activities. |
| 12 | Includes production of 90.8 MMboe from Woodside reserves and 0.5 MMboe primarily from feed gas purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector. |
| 13 | Comparisons are to half-year ended 30 June 2022. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 4 |
Net profit after tax reconciliation
The following table summarises the variance between the H1 2022 and H1 2023 results for the contribution of each line item to NPAT.
| 2022 H1 reported NPAT |
$1,640 million | |||||
| Sales revenue – volume from former BHPP assets |
+$2,532 million | Additional five months of contribution from former BHPP assets | ||||
| Sales revenue – price |
-$878 million | Lower realised prices across various price markers | ||||
| Sales revenue – volume other |
-$64 million | Reduction primarily due to the planned major turnarounds | ||||
| Cost of production |
-$500 million | Increase primarily driven by additional five months of contribution from former BHPP assets | ||||
| Oil and gas properties depreciation and amortisation |
-$1,020 million | Increase primarily driven by additional five months of contribution from former BHPP assets | ||||
| Other cost of sales |
-$114 million | Increase driven by the derecognition and unwind of the Corpus Christi onerous contract provision in H1 2022 | ||||
| Other income |
-$364 million | Decrease driven by the gain on Pluto Train 2 sell-down recognised in H1 2022 | ||||
| General, administrative and other costs |
+$305 million | Decrease primarily driven by merger transaction costs recognised in H1 2022 | ||||
| Impairment losses |
-$68 million | Recognition of impairment loss due to the reduction in future Pyrenees production volumes | ||||
| Income tax and PRRT expense |
+$186 million | Decrease primarily driven by recognition of the Trion deferred tax asset (DTA) offset by the derecognition of the Pluto PRRT DTA | ||||
| Other expenses |
+85 million | |||||
| 2023 H1 reported NPAT |
$1,740 million | |||||
| 2023 H1 NPAT adjustments |
+$156 million | Adjustment for derecognition of Pluto PRRT DTA, the recognition of the Pyrenees impairment loss and the recognition of the Trion DTA | ||||
| 2023 H1 underlying NPAT |
$1,896 million |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 5 |
Capital management
Interim dividend and dividend reinvestment plan
A 2023 interim fully franked dividend of 80 US cents per share (cps) has been declared. The total amount of the interim dividend payment is $1,519 million which represents approximately 80% of underlying NPAT for the first half of 2023, reflecting Woodside’s strong operational performance.14
The dividend reinvestment plan (DRP) was suspended on 27 February 2023.
Liquidity and debt service
During the half, Woodside generated $2,931 million of cash flow from operating activities and delivered positive free cash flow of $294 million.14,15
Woodside maintained its standby debt facilities at $4,050 million. Liquidity at the end of the period was $7,509 million and Woodside’s drawn debt at the end of the period was $5,109 million. Net debt at the end of the period increased 35% to $3,220 million, in line with planned capital expenditure.14
Woodside will continue to actively manage its debt portfolio throughout 2023.
Balance Sheet
Woodside’s commitment to an investment grade credit rating remains unchanged and supports Woodside’s aim of providing sustainable returns to shareholders and investing in future growth opportunities, in accordance with the capital allocation framework.
Woodside’s gearing at the end of 2022 was 1.6%, which is below our target range of 10% to 20%. The reduced cashflows driven by lower realised price, payments for capital and exploration expenditure, tax payments as well as the 2022 final dividend payment resulted in Woodside’s gearing increasing to 8.2% at the end of H1 2023.
A low level of net debt positions Woodside’s balance sheet for its expected future capital expenditure. As a result, Woodside’s gearing may at times fall outside the target range of 10% to 20% as the balance sheet is managed through the investment cycle.14
Commodity price risk management
Woodside hedges to protect the balance sheet against downside commodity price risk, particularly during periods of high capital expenditure.
As at 30 June 2023, Woodside has placed oil price hedges for:
| • | approximately 21.8 MMboe of 2023 production at an average price of $74.5 per barrel of which approximately 11.2 MMboe has been delivered |
| • | a further 6.2 MMboe of 2024 production at an average price of approximately $75.2 per barrel. |
Subsequent to the period, Woodside placed oil price hedges on a further 23.1 MMboe of 2024 production and has now hedged approximately 29.3 MMboe of 2024 production at an average price of approximately $75.7 per barrel.
Woodside has also placed a number of hedges for Corpus Christi LNG volumes to protect against downside pricing risk. These hedges are Henry Hub and Title Transfer Facility (TTF) commodity swaps. Approximately 81% of Corpus Christi volumes for the remainder of 2023 and approximately 29% of 2024 volumes have reduced pricing risk as a result of hedging activities.
| 14 | These are non-IFRS measures. Refer to Alternative Performance Measures for a reconciliation for these measures to Woodside’s financial statements on pages 51-52 and Non-IFRS Measures on page 56 for more information about non-IFRS measures. |
| 15 | Cash flow from operating activities less cash flow from investing activities. Free cash flow of $294 million includes the impact of collateral payments of $332 million against hedging activities. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 6 |
Operations
Pluto LNG
Pluto LNG is a gas processing facility in the Pilbara region of Western Australia, comprising an offshore platform and one onshore LNG processing train.
Woodside’s share of Pluto production in the first half of 2023 was 23.5 MMboe. This was a 3% decrease compared to the first half of 2022 due to planned turnaround activities. Sustained high reliability of 99.9% in the five months prior to the planned turnaround and the delivery of Pluto gas through the Pluto-Karratha Gas Plant (KGP) Interconnector (Interconnector) contributed to the strong overall production performance.
Woodside successfully completed a major turnaround on the onshore and offshore facilities, executing essential maintenance scopes to support continued safe, reliable and efficient production. The major turnaround included the installation of infrastructure to enable processing of Scarborough gas and tie-ins for Pluto Train 2.
Woodside is pursuing the opportunity to reduce Scope 1 greenhouse gas emissions at Pluto LNG by utilising solar energy from the proposed Woodside Solar project. The major turnaround included installation of additional electrical tie-in points for potential carbon-to-products value streams and for the importation of solar energy from Woodside Solar.
The Pluto Remote Operations Centre in Perth became fully operational in June 2023 with day-to-day operations of Pluto LNG now being undertaken remotely by our Perth-based team.
Woodside is operator and holds a 90% participating interest.
North West Shelf Project
The North West Shelf Project (NWS) consists of three offshore platforms and the onshore Karratha Gas Plant, which includes five onshore LNG processing trains. It produces LNG, condensate, pipeline gas and natural gas liquids (NGLs).
Woodside’s share of production in the first half of 2023 was 22.7 MMboe. This was a 73% increase compared to the first half of 2022 due to the increase of Woodside’s equity share following completion of the merger in June 2022. Gas processing operations through the Interconnector continued with 5.4 MMboe of Pluto gas processed in H1 2023.
KGP is expected to have increased ullage in 2024 due to a combination of natural field decline and limited third-party gas processing demand. To reduce operating costs, NWS is assessing taking one LNG train offline. Discussions continue between NWS and other resources owners for the processing of third-party gas and NWS continues to evaluate infill and nearfield opportunities to utilise ullage at KGP.
NWS is on track to receive Waitsia gas for processing.
The Browse and NWS joint ventures are progressing negotiation of key commercial terms in support of the Browse to NWS development concept. Browse is a large backfill opportunity to fill long-term NWS ullage due to the quantity and the compatibility of the gas resource with the KGP facilities.
The NWS Project Extension proposal remains subject to an ongoing WA statutory appeals process. The proposal supports the long-term operations and future processing of third-party gas resources. The Commonwealth Environment Protection and Biodiversity Conservation Act (EPBC) assessment remains paused until the appeals process is completed. Engagement with the Commonwealth regulator continues.
Woodside is operator and holds a 33.33% participating interest.16
Wheatstone and Julimar-Brunello
Wheatstone is an LNG processing facility near Onslow, Western Australia, comprising an offshore production platform and two onshore LNG production trains. It processes gas from several offshore gas fields including Julimar and Brunello.
| 16 | The North West Shelf consists of a number of active joint ventures. Woodside’s participating interest is 33.33% in all of these apart from the joint ventures with CNOOC. Woodside’s participating interest in the CLNG JV is 25% and in the Extended Interest JVs is 31.567%. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 7 |
Woodside’s share of Wheatstone production in the first half of 2023 was 6.6 MMboe. This was a 27% increase compared to the first half of 2022, which was impacted by a major facility turnaround.
The FID on Julimar-Brunello Phase 3 was approved in April 2023. The project involves the drilling of up to four development wells tied-back from the Julimar field to the existing Julimar field production system.
Woodside is operator and holds a 65% participating interest in the Julimar-Brunello fields. Woodside holds a 13% non-operating interest in the Wheatstone project.
Bass Strait
The Bass Strait is located in the south-east of Australia and produces oil and gas through a network of offshore platforms, pipelines and onshore processing facilities. The Bass Strait assets include the Gippsland Basin Joint Venture (GBJV) and Kipper Unit Joint Venture (KUJV). Kipper Unit production is processed by the GBJV under a processing agreement.
Woodside’s share of production from the Bass Strait was 10.9 MMboe in H1 2023, an increase from 3.3 MMboe in H1 2022.17 All gas produced by the GBJV is supplied into the eastern Australian domestic gas market, supporting Australia’s energy needs.
The GBJV continued significant decommissioning activity through the period, permanently plugging 10 wells on the Flounder platform and removing conductors of 31 wells on the Fortescue platform. The GBJV also executed an agreement to charter a fourth semi-submersible vessel to support decommissioning activities from the end of 2023.
Woodside holds a 50% non-operating interest in the GBJV and a 32.5% non-operating interest in the KUJV.
Other Australian oil and gas assets
Woodside operates three floating production storage and offloading (FPSO) facilities off the north-west coast of Western Australia. These are the Okha FPSO (Woodside interest: 50%), Ngujima-Yin FPSO (Woodside interest: 60%) and Pyrenees FPSO (Woodside interest: 40% in WA-43-L and 71.4% in WA-42-L).
Woodside’s share of production from the FPSO assets was 3.1 MMboe in H1 2023. This was a 35% decrease from H1 2022 primarily due to the planned five-yearly Ngujima-Yin FPSO maintenance turnaround performed in Singapore. Production on Ngujima-Yin recommenced in July 2023.
Macedon (Woodside interest: 71.4%), also operated by Woodside, is a gas project located near Onslow, Western Australia which produces pipeline gas for the Western Australian domestic gas market.
Woodside’s share of production from Macedon was 4.1 MMboe, up from 0.7 MMboe in H1 2022.17 The Macedon facility delivered approximately 17% of the Western Australian domestic gas market supply in H1 2023.
Gulf of Mexico
Woodside interests in the US Gulf of Mexico includes the conventional oil and gas developments of the Shenzi tension leg platform (TLP) (operated; Woodside interest: 72%), Atlantis floating production unit (FPU) (non-operated; Woodside interest: 44%), and Mad Dog A-spar and Argos FPU (non-operated; Woodside interest: 23.9%).
Woodside’s share of production from the Gulf of Mexico assets was 14.8 MMboe in H1 2023.
First production was successfully achieved in April 2023 at the Argos platform for Mad Dog Phase 2, a development on the southern flank of the Mad Dog field. Production ramp-up is expected to continue through 2023.
A successful appraisal well, SWX4, was drilled in the south-west part of the Mad Dog field. An extension of the current development through a multi-well tie-back to Argos is being evaluated.
Both wells were completed on Shenzi North, a two-well subsea tieback to the Shenzi TLP. Subsea activities are ongoing with one of three campaigns complete, installing manifolds and high-integrity pressure protection system packages. The project is ahead of the original 2024 target schedule and is now expecting first oil in 2023.
| 17 | The increase in production is driven by an additional five months of contributions from the former BHPP assets. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 8 |
Greater Angostura
Greater Angostura includes the Angostura and Ruby conventional oil and gas fields, located offshore Trinidad and Tobago. The development includes an offshore central processing facility and five well head platforms.
Woodside continues to pursue opportunities to maximise value and safely optimise production and operating cost. Woodside’s share of production from Greater Angostura was 5.6 MMboe in H1 2023.
Woodside is operator of both fields and holds a 45% participating interest in the Angostura field and a 68.5% participating interest in the Ruby field.
Decommissioning
The Enfield plug and abandonment campaign continued with eight wells permanently plugged. As at the end of the period, the plugging of 13 of 18 wells and removal of 16 of 18 xmas trees have been completed.
Preparations for the planned removal of the Nganhurra riser turret mooring (RTM) in Q4 2023 remain on track, with the Nganhurra RTM decommissioning environmental plan being accepted by the regulator in late July 2023.
Woodside has awarded several major contracts for the decommissioning of subsea infrastructure at the Enfield, Griffin (including the RTM), Stybarrow (including the Disconnectable Turret Mooring) and Echo Yodel oil and gas fields offshore Western Australia. Award of these contracts support commencement of major offshore activities in Q4 2023.
Marketing and Trading
A long-term gas sale and purchase agreement (GSPA) with Perdaman Chemicals and Fertiliser Pty Ltd became unconditional in April 2023. Supply under the GSPA is for approximately 130 terajoules per day of gas over a term of 20 years, commencing upon commissioning of the plant expected in 2026 or 2027.
Woodside executed several natural gas sale agreements for the combined supply of approximately 120 petajoules of pipeline gas, to both eastern and Western Australian domestic customers including retailers and commercial and industrial users. Delivery is expected to take place from Q4 2023 to 2026.
In July 2023, the mandatory Gas Code of Conduct (the Code) which applies to Australia’s east coast gas market commenced. The Code was introduced by the Australian Government following consultation with stakeholders. Woodside is working to ensure it satisfies its compliance obligations under the code.
In August 2023, Woodside and LNG Japan Corporation entered into a non-binding heads of agreement for the sale and purchase of 12 LNG cargoes per year (approximately 0.9 million tonnes per annum) for ten years commencing in 2026. This agreement is part of a broader strategic relationship with LNG Japan and its parent entities which includes the sale of a 10% interest in Scarborough and collaboration on opportunities in new energy.
Projects
Scarborough
The Scarborough gas field is located in the Carnarvon Basin, approximately 375 km off the coast of Western Australia. The development includes installation of a FPU with eight wells drilled in the initial phase and 13 wells drilled over the life of the Scarborough field.
Expansion of Pluto LNG includes the construction of a second LNG train (Pluto Train 2), installation of additional domestic gas processing facilities and supporting infrastructure, and modifications to Pluto Train 1 to allow it to process Scarborough gas.
The Scarborough upstream pipeline manufacturing was completed in H1 2023, with insulation coating work continuing in Indonesia. Fabrication of the FPU topsides and hull continued to progress.
Following acceptance of the Scarborough Trunkline Installation (State Waters) Environmental Plan in April 2023, shore crossing preparations at Pluto commenced and are nearing completion. Subsea flowline fabrication also continued in preparation for reeling.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 9 |
The National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA) accepted the Marine Seismic Survey Environment Plan in July 2023, subject to conditions. Engagement with NOPSEMA continued regarding the remaining Commonwealth Environment Plans.
Pluto Train 2 module fabrication and foundation site works progressed and the construction accommodation village was completed and is now fully available for use.
Pluto Train 1 modifications pre-execution phase activities progressed with design activities and market engagement for long-lead items procurement underway.
In August 2023, Woodside entered into a sale and purchase agreement with LNG Japan for the sale of a 10% non-operating participating interest in the Scarborough Joint Venture (the Transaction).18 The purchase price is US$500 million, subject to adjustments. LNG Japan will also reimburse Woodside for its share of expenditure for the Scarborough project from 1 January 2022, the effective date of the Transaction. On completion of the Transaction, expected in the first quarter of 2024, the estimated total consideration comprising the purchase price, reimbursed expenditure and escalation is approximately US$880 million. On completion, Woodside will hold a 90% interest in the Scarborough Joint Venture and remain as operator.
Woodside is targeting first LNG cargo in 2026.
Woodside is operator and has a 100% participating interest in Scarborough and a 51% participating interest in Pluto Train 2.
Sangomar Field Development Phase 1
The Sangomar Field Development Phase 1 is Senegal’s first offshore oil project and includes a stand-alone FPSO and supporting subsea infrastructure. It is designed to allow the tie-in of subsequent phases.
During the first half of 2023, FPSO topside integration and pre-commissioning work progressed at the Keppel Shipyard in Singapore.
In Senegal, the subsea installation campaign progressed, with installation 76% complete and the overall subsea work scope 95% complete at the end of the period. Installation and testing of the rigid flowlines, totalling 101 km in length, were successfully and safely completed.
The drilling and completions campaign involves the drilling of 23 production, gas and water injection wells. At the end of June 2023, 12 wells were complete and 11 further wells were partially complete.
In May 2023, the Sangomar Joint Venture approved the drilling of an additional well to optimise field recovery. The drilling is expected to be completed by the Ocean BlackRhino while the drillship is offshore Senegal completing the Sangomar Field Development Phase 1 drilling.
Woodside is targeting first oil in mid-2024.
Woodside is operator and has an 82% participating interest in the project.
Trion
Trion is an oil field located approximately 180 km off the Mexican coastline and 30 km south of the US/Mexico maritime boarder. The Trion project includes a semi-submersible FPU capable of producing and transferring 100,000 barrels of oil per day to a floating storage and offloading (FSO) vessel. Oil from the FSO is expected to be exported to the market, with excess gas transferred to existing offshore gas export infrastructure. Key technical, commercial, and regulatory activities progressed in the first half of 2023 and Woodside made a FID on the development in June 2023. Woodside’s net equity Scope 1 and Scope 2 emissions reduction targets remain unchanged by this decision.19,20
| 18 | LJ Scarborough Pty Ltd (LNG Japan) is currently a wholly owned subsidiary of LNG Japan Corporation, which is a 50:50 joint venture between Sumitomo Corporation and Sojitz corporation. |
| 19 | Woodside’s net equity Scope 1 and Scope 2 greenhouse gas emissions reduction targets are for net equity Scope 1 and 2 GHG emissions, with a targeted reduction of 15% by 2025 and 30% by 2030, and an aspiration of net zero by 2050. The net emissions reduction targets are relative to a starting base representative of the gross annual average equity Scope 1 and 2 GHG emissions over 2016-2020 and may be adjusted (up or down) for potential equity changes in producing or sanctioned assets with a final investment decision prior to 2021. Refer to the Glossary and Woodside’s Climate Report 2022 for further information on the way in which Woodside defines and calculates greenhouse gas emissions. |
| 20 | Emissions resulting from Trion are subject to Woodside’s net equity Scope 1 and 2 greenhouse gas emissions reduction target and its net zero aspiration. These emissions will be managed in accordance with Woodside’s decarbonisation strategy using the plans and practices disclosed in Woodside’s Climate Report 2022. See sections 3.5 and 3.6 of Woodside’s Climate Report 2022 for further information. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 10 |
Long-lead items were placed on order for topsides rotating equipment and key manufacturing slots. Early engineering was initiated with the nominated FPU engineering subcontractors in May 2023 and the FPU engineering, procurement and construction contract was executed with Hyundai Heavy Industries in June 2023. The FPU will be constructed in the Republic of Korea.
Subsequent to the period, the rig contract was awarded and the FPU and FSO installation contract was awarded. The remaining major contracts will continue to be executed progressively.
The field development plan (FDP) was approved by the Trion Joint Venture in June 2023 and has been submitted to the regulator. The FDP is under review by the regulator and approval is expected in the second half of 2023.
Woodside is targeting first oil in 2028.
Woodside is operator and has a 60% participating interest in the project.
Exploration and Development
Browse
The Browse development comprises the Calliance, Brecknock and Torosa gas and condensate fields located approximately 425 km north of Broome, Western Australia.
The CCS infrastructure to abate Browse reservoir CO2 has been incorporated into the development concept and regulatory approval processes are ongoing.
Commercial discussions continue between the Browse and NWS joint ventures to support the processing of Browse resources through the NWS Project’s Karratha Gas Plant.
We continue to engage the regulator on environmental approvals.
Woodside is operator and holds a 30.6% participating interest.
Calypso
Calypso is located approximately 220 km off the coast of Trinidad in 2,100m water depth. The resource comprises several gas discoveries in Block 23(a) and Block TTDAA 14. The development is located in a region with existing infrastructure and a favourable demand outlook.
In the half, Woodside completed conceptual studies to select an infield host as the preferred development concept. Pre-FEED engineering is expected to commence in the second half of 2023 to mature the definition of the concept.
Marketing and commercial discussions continue with key stakeholders to evaluate options to monetise the resource.
Woodside is operator and holds a 70% participating interest.
Sunrise
The Sunrise development comprises the Sunrise and Troubadour gas and condensate fields which are located approximately 450 km north-west of Darwin and 150 km south of Timor-Leste.
The Sunrise Joint Venture participants continue to engage the Australian and Timor-Leste Governments on a new Greater Sunrise Production Sharing Contract (PSC), which is required under the Maritime Boundary Treaty between Timor-Leste and Australia. The Sunrise Joint Venture also announced a commitment to undertake a concept select study program for the development of the Greater Sunrise fields in parallel with the ongoing PSC discussions.
Woodside is operator and holds a 33.44% participating interest.
Exploration
Woodside continued to build its position in the US Gulf of Mexico, acquiring five leases (four operated and one non-operated) in lease sale 259. Woodside also acquired a 44% working interest in two leases in Green Canyon and spudded the Spinel well with co-owner and operator BP in early June 2023.
Woodside is planning to spud the Gemtree exploration well in the second half of 2023. Gemtree is a potential tie back to Wheatstone via Julimar Brunello.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 11 |
The Egyptian regulator approved Woodside’s acquisition of a 27% interest in two non-operated blocks in the Herodotus Basin. Subsequent to the period, Woodside and the co-owners elected to enter the second exploration phase for one of the blocks.
In March, Woodside signed an option agreement to acquire at least a 56% interest in Petroleum Exploration License 87, located offshore Namibia in the Orange Basin. Seismic acquisition was completed in May 2023 and a decision on exercising the option to enter will follow evaluation of seismic data.
Woodside also continued to optimise its exploration portfolio, exiting blocks that are no longer considered prospective. This included a decision to exit Block 5 in deepwater Trinidad & Tobago and completing formal exit activities in Canada, Republic of Korea and Myanmar Block A-6.
New energy and carbon solutions
Woodside’s new energy strategy is centred on building relationships across the value chain and developing profitable solutions to meet customer requirements that have the ability to scale to match the pace of the energy transition.21 We are working with customers to develop demand for new sources of energy, while leveraging our competitive advantage as a safe and reliable producer and supplier of energy to customers across the globe.
New energy collaboration
As part of its strategic collaboration with LNG Japan, Woodside entered into non-binding agreements to collaborate with Sumitomo Corporation and Sojitz Corporation on global opportunities in new energy which could include ammonia, hydrogen, carbon capture and storage (CCS) and carbon management technology.
H2OK
H2OK is a proposed liquid hydrogen project to be located in Ardmore, Oklahoma with an expected capacity of 60 tonnes per day (tpd) of liquid hydrogen produced through electrolysis. The project is initially targeting the supply of hydrogen to the heavy transport sector.
Woodside has progressed contracting activities for the plant construction scope and other schedule critical packages. In May 2023, Woodside purchased 94 acres of land in the Westport Industrial Park in Ardmore, Oklahoma, for the proposed H2OK facility.
Woodside is actively marketing hydrogen offtake and is advancing a number of agreements in support of FID readiness in 2023.
Woodside is operator and holds a 100% participating interest.
H2Perth
H2Perth is a proposed hydrogen and ammonia production facility to be located in Perth, Western Australia. Phase 1 of the project is targeting up to 2,700 tpd of ammonia produced through gas reforming and electrolysis. It is targeting supply to local industry and international users. Subsequent phases have the potential to expand to 8,900 tpd by increasing the electrolysis component.
Woodside submitted primary environmental approval application documents to both the Commonwealth and Western Australian regulators in May 2023.
Woodside is operator and holds a 100% participating interest.
Hydrogen Refueller @H2Perth
The Hydrogen Refueller @H2Perth is a proposed self-contained hydrogen production, storage and refuelling facility, to be built on approximately 1.5 ha of industrial land adjacent to Woodside’s proposed H2Perth project. Woodside is targeting production at the Refueller of 0.2 tpd of gaseous hydrogen, with the potential to scale up to a targeted 1.0 tpd. Woodside is targeting the supply of hydrogen to Western Australian industrial and public customers.
In H1 2023, Woodside awarded a contract for the engineering and fabrication of the hydrogen production equipment and submitted primary Western Australian environmental approval documents. Woodside also executed an agreement with the State of Western Australia for funding under the Hydrogen Fuelled Transport Program for the Hydrogen Refueller @H2Perth.
| 21 | Refer to the Glossary for further information on the way in which Woodside defines new energy. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 12 |
Woodside is operator and holds a 100% participating interest.
H2TAS
Woodside has a proposed renewable ammonia and hydrogen production facility to be located in the Bell Bay area of Tasmania. H2TAS is planned to be a phased development, targeting an initial capacity of up to 550 tpd of ammonia. Ammonia would be produced through electrolysis, utilising a combination of wind and hydroelectric power.
Woodside continues to evaluate renewable power solutions and offtake options that would enable the project to progress.
Woodside Solar
Woodside is progressing the proposed Woodside Solar project, which plans to generate electricity from a solar photovoltaic farm located in an industrial estate approximately 15 km south-west of Karratha in Western Australia, complemented by a battery energy storage system. The facility is expected to initially supply approximately 50 MW of solar energy to Pluto LNG potentially reducing Woodside’s Scope 1 greenhouse gas emissions with potential to expand the project in the future.
In H1 2023, Woodside progressed engineering development of the solar generation, battery energy storage and transmission infrastructure required for the power opportunity and completed heritage surveys for the proposed initial solar development site. Engagement with local, state and commonwealth authorities on key development and environmental approvals continued.
In preparation for potential solar energy import to Pluto LNG, key electrical tie-in points were installed during the 2023 Pluto turnaround.
Woodside is targeting FID readiness in 2023.
Woodside is operator and holds a 100% participating interest.
Southern Green Hydrogen
Southern Green Hydrogen is a proposed hydrogen and ammonia facility to be located in Southland, New Zealand. The proposal is targeting up to 1,400 tpd of ammonia and is expected to utilise renewable power to produce hydrogen and ammonia for export and domestic supply.
Carbon capture and storage (CCS)
Woodside, as a participant in various joint ventures, holds three greenhouse gas assessment permits. These permits enable carbon capture and storage assessments in the Browse Basin (operated), Northern Carnarvon Basin (operated) and Bonaparte Basin (non-operated).
Woodside is progressing activities to support submission of the environmental referral for the Northern Carnarvon CCS. These activities include environmental surveys and preparations for heritage surveys.
Woodside is also a participant in the SEA CCS hub, located in the Gippsland Basin off the coast of Victoria. Phase 1 of the project, which aims to utilise existing infrastructure to capture and store CO2 in the depleted Bream reservoir located offshore Victoria, progressed to FEED in H1 2023.
Carbon origination
Woodside established a carbon business in 2018 to develop a carbon credits portfolio and our own carbon origination projects in support of our emissions reduction targets and regulatory obligations. We acquire carbon credits through market purchase and through the development of our own carbon origination projects. The carbon portfolio is dynamic and we continue to develop and seek to optimise it, to give Woodside flexibility in response to changes in regulatory requirements and corporate climate strategy as they arise.
In 2020, Woodside commenced the Native Reforestation Project, with the aim of originating our own biodiverse carbon plantings in Western Australia. During H1 2023, Woodside began planting activities on approximately 5,600 ha of land at Woodside owned properties. The full year program is forecast to plant over 2.7 million mixed biodiverse seedlings. These activities were 40% complete by the end of H1 2023. The project has a potential to sequester approximately 2,000 kt CO2-e over 25 years.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 13 |
Other new energy investments
Woodside and Heliogen have a project agreement to deploy a 5 MW module of Heliogen’s artificial intelligence-enabled concentrated solar energy technology in California. The project is progressing through FEED. In addition, Heliogen and Woodside have a collaboration agreement to jointly market Heliogen’s renewable energy technology in Australia.
Woodside has investments in LanzaTech and String Bio which seek to convert carbon into useful products through carbon capture and utilisation (CCU) and continues to assess opportunities to deploy their technologies in demonstration-scale pilot projects ahead of their potential deployment on a larger-scale.
Climate and Sustainability
Climate
Woodside released its Climate Report 2022 which summarises Woodside’s climate-related plans, activities, progress and climate-related data for the period 1 January 2022 to 31 December 2022. The report has been structured to align with the Task Force on Climate-related Financial Disclosures (TCFD) recommendations framework.
Asset decarbonisation plans were developed for the former BHP assets. Decarbonisation plans have now been developed for all operated Woodside assets and projects and will be reviewed annually in line with asset strategic planning processes to maintain their currency and to continue to identify opportunities as costs and technologies improve.
As a part of Woodside’s ongoing focus on reducing methane emissions, H1 2023 activities included independent satellite and aerial surveys to measure onshore methane emissions, and changes to operating procedures in our LNG process.
In our Climate Report 2022, we identified six key climate-related considerations which we may factor into investment decisions for opportunities through an uncertain energy transition. They were applied to the Trion investment decision and demonstrate how Woodside assessed that Trion is expected to be resilient in a decarbonising world.22
We continued to engage with shareholders and other stakeholders on Woodside’s climate strategy. Woodside intends to put its climate disclosures to a non-binding, advisory vote at its annual general meeting in 2024.
Health, Safety & Environment
An incident occurred on the North Rankin Complex in June 2023 which resulted in the fatality of a contractor employee. Woodside’s investigations into the incident are ongoing. Immediate actions have been implemented by Woodside and preliminary lessons shared with industry.
Woodside experienced one Tier 1 loss of primary containment process safety event at Pluto LNG in the first half of 2023. The contributing factors to this event are understood with corrective actions identified.
Subsequent to the period, a loss of primary containment process safety event occurred at the Angostura field in Trinidad and Tobago. Woodside shut down offshore production operations at the facility and production was restarted following successful completion of relevant safety checks across the facility. Woodside’s investigation is ongoing.
The year-to-date total recordable injury rate was 1.72 per million work hours compared to 1.80 recorded for full-year 2022. Woodside is focusing on our system of safety, learning from events and enhancing monitoring of key controls to improve our overall safety performance.
Environmental performance remained strong in the first half of 2023, with zero significant environmental events.
Supporting local suppliers
Woodside increased its year-on-year value of awarded contracts to local and Indigenous suppliers, and increased visibility of commercially sustainable contracting opportunities for our local and Indigenous suppliers to our operations and projects.
| 22 | Refer to page 27 of Woodside’s Climate Report 2022 and slide 9 of the announcement ‘Woodside Approves Investment in Trion Development” for further information on the six key-climate related considerations. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 14 |
Woodside continues to work with its key Sangomar contractors to provide opportunities for Senegalese people and suppliers, whilst meeting the requirements of in-country local content legislation. Woodside has also continued to grow local contracting opportunities in Trinidad and the Gulf of Mexico.
Communities
Woodside released a report on progress made in the second year of its 2021-2025 Reconciliation Action Plan. The report highlighted achievements and areas for improvement in the areas of respect for culture and heritage, economic participation and further developing capability and capacity.
Woodside’s 2022 Social Contribution Impact Report was released in early 2023, further demonstrating our commitment to creating positive outcomes in the community and progress against Woodside’s Sustainable Development Goals.
Social impact assessments (SIA) were completed for Karratha and Roebourne in the north-west of Australia, and for the Trion Project in Mexico.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 15 |
Principal risks and uncertainties
There are several risk factors or uncertainties that could result in a material effect on the company’s results over the next six months. These risks and uncertainties may occur as a result of Woodside’s activities globally, including in connection with its operated (or non-operated) assets, and third parties engaged through the value chain.
Information on Woodside’s risks and how they are managed can be found on pages 33-40 of the Annual Report 2022. There have been no material changes to the risk factors described in the Annual Report 2022 since the date of that report. The risks are summarised below (in no particular order).
| Climate change | The global response to climate change is changing the way the world produces and consumes energy. The complex and pervasive nature of climate change means transition risks are interconnected with and may amplify other risks. Additionally, the inherent uncertainty of potential societal responses to climate change may create a systemic risk to the global economy. Climate change may also create significant physical risks, such as increased frequency and severity of storms, wildfires, floods and other climatic events, as well as chronic shifts in temperature and precipitation patterns. | |
| Social licence to operate | Risks associated with actual or alleged deviation from social or business expectations of ethical behaviour (including breaches of laws or regulations) and social responsibility (including environmental impact and community contribution), particularly as these expectations evolve. | |
| Growth | Risks associated with delivery of both major and complex multi-year execution project activities across multiple global locations, including a reliance on third parties for materials, products, and services as well as risks associated with integration, acquisitions and divestments. | |
| Operations | Due to the nature of our operations, Woodside and neighbouring communities are potentially exposed to a broad range of risks. This is a result of factors such as the geographical range, operational diversity and technical complexity of our assets. These types of risks include health and safety; commercial; regulation; and reserves and resources estimates. | |
| Finance and market | Risks associated with the ability to capture value whether markets are stable or volatile, and manage the risks associated with interest rate, commodity price and foreign exchange fluctuations and inflation. | |
| People and culture | Risks associated with the ability to attract, retain, develop and motivate key employees to succeed and safeguard both current or future performance and growth. | |
| Digital and cybersecurity | Risks associated with adopting and implementing new technologies, whilst safeguarding our digital information and landscape (including from cyber threats) across our value chain. | |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 16 |
Directors’ Report
The directors of Woodside Energy Group Ltd present their report (including the review of operations of Woodside Energy Group Ltd and its controlled entities (Group) set out on pages 1-16 which forms part of this report) together with the Half-Year Financial Statements of the Group.
Board of directors
The names of directors in office during or since the end of the 2023 half-year are as follows:
| Mr Richard Goyder, AO (Chair) | Ms Meg O’Neill (CEO and Managing Director) | |
| Mr Larry Archibald | Mr Arnaud Breuillac (appointed 8 March 2023) | |
| Mr Frank Cooper, AO | Ms Swee Chen Goh | |
| Ms Angela Minas (appointed 28 April 2023) | Mr Ian Macfarlane | |
| Ms Ann Pickard | Mr Gene Tilbrook | |
| Mr Ben Wyatt | Dr Christopher Haynes, OBE (retired 28 April 2023) | |
| Dr Sarah Ryan (retired 28 April 2023) |
Rounding of amounts
Woodside Energy Group Ltd is an entity to which the Australian Securities and Investments Commission (ASIC) Corporations (Rounding in Financial/Directors’ Reports) Instrument 2016/191 (ASIC Instrument 2016/191) applies. Amounts in this report have been rounded in accordance with ASIC Instrument 2016/191. This means that amounts contained in this report have been rounded to the nearest million dollars, unless otherwise stated.
Auditor’s Independence Declaration
The Auditor’s Independence Declaration, as required under section 307C of the Corporations Act 2001, is set out on page 18 and forms part of this report.
Signed in accordance with a resolution of the directors.
R J Goyder, AO
Chair
Perth, Western Australia
22 August 2023
| Woodside Energy Group Ltd | Half-Year Report 2023 | 17 |
Auditor’s Independence Declaration to the Directors of Woodside Energy Group Ltd
Auditor’s Independence Declaration
As lead auditor for the review of Woodside Energy Group Ltd for the half-year ended 30 June 2023, I declare that to the best of my knowledge and belief, there have been:
| (a) | no contraventions of the auditor independence requirements of the Corporations Act 2001 in relation to the review; and |
| (b) | no contraventions of any applicable code of professional conduct in relation to the review. |
This declaration is in respect of Woodside Energy Group Ltd and the entities it controlled during the period.
| N M Henry |
| Partner, PricewaterhouseCoopers Perth, Western Australia 22 August 2023 |
PricewaterhouseCoopers, ABN 52 780 433 757
Brookfield Place, 125 St Georges Terrace, PERTH WA 6000, GPO Box D198, PERTH WA 6840
T: +61 8 9238 3000, F: +61 8 9238 3999, www.pwc.com.au
Liability limited by a scheme approved under Professional Standards Legislation.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 18 |
HALF-YEAR FINANCIAL
STATEMENTS
for the half-year ended 30 June 2023
| Woodside Energy Group Ltd | Half-Year Report 2023 | 19 |
HALF-YEAR FINANCIAL STATEMENTS
CONTENTS
| CONDENSED CONSOLIDATED INCOME STATEMENT |
21 | |||||
| CONDENSED CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME |
22 | |||||
| CONDENSED CONSOLIDATED STATEMENT OF FINANCIAL POSITION |
23 | |||||
| CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS |
24 | |||||
| CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY |
25 | |||||
| NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS |
26 | |||||
| A. |
Earnings for the period | 28 | ||||
| A.1 Segment revenue and expenses | 28 | |||||
| A.2 Finance costs | 29 | |||||
| A.3 Dividends paid and proposed | 29 | |||||
| A.4 Earnings per share | 29 | |||||
| A.5 Taxes | 30 | |||||
| B. |
Production and growth assets | 31 | ||||
| B.1 Exploration and evaluation | 31 | |||||
| B.2 Oil and gas properties | 32 | |||||
| B.3 Impairment of exploration and evaluation and oil and gas properties | 33 | |||||
| B.4 Business combination | 34 | |||||
| C. |
Debt and capital | 36 | ||||
| C.1 Contributed equity | 36 | |||||
| C.2 Interest-bearing liabilities and financing facilities | 36 | |||||
| D. |
Other assets and liabilities | 37 | ||||
| D.1 Segment assets and liabilities | 37 | |||||
| D.2 Provisions | 37 | |||||
| D.3 Other financial assets and liabilities | 38 | |||||
| E. |
Other items | 41 | ||||
| E.1 Contingent liabilities and assets | 41 | |||||
| E.2 Changes to the composition of the Group | 41 | |||||
| E.3 New standards and interpretations | 41 | |||||
| E.4 Events after the end of the reporting period | 41 | |||||
| DIRECTORS’ DECLARATION |
42 | |||||
| INDEPENDENT REVIEW REPORT |
43 | |||||
Significant changes in the current reporting period
Financial performance for the half-year ended 30 June 2023 includes six months of BHPP results, as compared to one month of results in the comparative half-year ended 30 June 2022.
The financial performance and position of the Group were particularly affected by the following events and transactions during the reporting period:
| • | In April 2023, Mad Dog Phase 2 in the US Gulf of Mexico achieved its first production at the Argos platform. During the half-year ended 30 June 2023, Mad Dog Phase 2 produced 0.64 Mboe of hydrocarbons. Production will continue to ramp up in 2023. |
| • | On 20 June 2023, the Group made a final investment decision (FID) to develop the Trion resource in Mexico. Related exploration and evaluation assets were transferred to oil and gas properties (refer to Notes B.1 and B.2). As a result of the FID, the Group has recognised deferred tax assets (DTA) of $319 million (refer to Note A.5). |
| • | During the half-year ended 30 June 2023, the Group reduced the Pluto petroleum resource rent tax (PRRT) DTA by $637 million ($446 million post-tax) on the basis of future taxable profits not being available to utilise the deductible expenditure. This is primarily driven by decreases in forecast pricing assumptions and actual pricing realised during the half-year ended 30 June 2023. |
| • | The Group recognised a pre-tax impairment of $68 million for the Pyrenees cash-generating unit, primarily due to a reduction in future production volumes (refer to Note B.3). |
| • | In April 2023, conditions precedent were achieved in the long-term gas sale and purchase contract (GSPA) with Perdaman. The contract price contains an embedded derivative linked to the price of Urea, which is recognised as a liability of $52 million at 30 June 2023 (refer to Note D.3). |
| • | In 2023, the Group has completed the purchase price accounting for the BHP Petroleum (BHPP) merger (refer to Note B.4). |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 20 |
CONDENSED CONSOLIDATED INCOME STATEMENT
for the half-year ended 30 June 2023
| Notes | 2023 US$m |
2022 US$m |
||||||||||
| Operating revenue |
A.1 | 7,400 | 5,810 | |||||||||
| Cost of sales |
A.1 | (3,872 | ) | (2,238 | ) | |||||||
|
|
|
|
|
|||||||||
| Gross profit |
3,528 | 3,572 | ||||||||||
| Other income |
A.1 | 134 | 498 | |||||||||
| Other expenses |
A.1 | (803 | ) | (1,088 | ) | |||||||
| Impairment losses |
A.1 | (68 | ) | — | ||||||||
|
|
|
|
|
|||||||||
| Profit before tax and net finance costs |
2,791 | 2,982 | ||||||||||
| Finance income |
174 | 31 | ||||||||||
| Finance costs |
A.2 | (137 | ) | (86 | ) | |||||||
|
|
|
|
|
|||||||||
| Profit before tax |
2,828 | 2,927 | ||||||||||
| Petroleum resource rent tax (PRRT) expense |
(778 | ) | (424 | ) | ||||||||
| Income tax expense |
A.5 | (284 | ) | (824 | ) | |||||||
|
|
|
|
|
|||||||||
| Profit after tax |
1,766 | 1,679 | ||||||||||
|
|
|
|
|
|||||||||
| Profit attributable to: |
||||||||||||
| Equity holders of the parent |
1,740 | 1,640 | ||||||||||
| Non-controlling interest |
26 | 39 | ||||||||||
|
|
|
|
|
|||||||||
| Profit for the period |
1,766 | 1,679 | ||||||||||
|
|
|
|
|
|||||||||
| Basic earnings per share attributable to equity holders of the parent (US cents) |
A.4 | 91.7 | 145.5 | |||||||||
|
|
|
|
|
|||||||||
| Diluted earnings per share attributable to equity holders of the parent (US cents) |
A.4 | 91.1 | 144.0 | |||||||||
|
|
|
|
|
|||||||||
The accompanying notes form part of the half-year financial statements.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 21 |
CONDENSED CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
for the half-year ended 30 June 2023
| 2023 US$m |
2022 US$m |
|||||||
| Profit for the period |
1,766 | 1,679 | ||||||
|
|
|
|
|
|||||
| Other comprehensive income |
||||||||
| Items that may be reclassified to the income statement in subsequent periods: |
||||||||
| Gains/(losses) on cash flow hedges |
413 | (1,582 | ) | |||||
| Losses on cash flow hedges reclassified to the income statement |
241 | 255 | ||||||
| Tax recognised within other comprehensive income |
(76 | ) | 270 | |||||
| Exchange fluctuations on translation of foreign operations taken to equity |
1 | 2 | ||||||
| Items that will not be reclassified to the income statement in subsequent periods: |
||||||||
| Net (loss)/gain on financial instruments at fair value through other comprehensive income |
(23 | ) | 4 | |||||
|
|
|
|
|
|||||
| Other comprehensive income/(loss) for the period, net of tax |
556 | (1,051 | ) | |||||
|
|
|
|
|
|||||
| Total comprehensive income for the period |
2,322 | 628 | ||||||
|
|
|
|
|
|||||
| Total comprehensive income attributable to: |
||||||||
| Equity holders of the parent |
2,296 | 589 | ||||||
| Non-controlling interest |
26 | 39 | ||||||
|
|
|
|
|
|||||
| Total comprehensive income for the period |
2,322 | 628 | ||||||
|
|
|
|
|
|||||
The accompanying notes form part of the half-year financial statements.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 22 |
CONDENSED CONSOLIDATED STATEMENT OF FINANCIAL POSITION
As at 30 June 2023
| Notes | 30 June 2023 US$m |
31 December 2022 US$m |
||||||||
| Current assets |
||||||||||
| Cash and cash equivalents |
3,469 | 6,201 | ||||||||
| Receivables |
1,223 | 1,578 | ||||||||
| Inventories |
700 | 678 | ||||||||
| Other financial assets |
D.3 | 373 | 677 | |||||||
| Tax receivable |
101 | 73 | ||||||||
| Other assets |
92 | 83 | ||||||||
|
|
|
|
|
|||||||
| Total current assets |
5,958 | 9,290 | ||||||||
|
|
|
|
|
|||||||
| Non-current assets |
||||||||||
| Receivables |
802 | 845 | ||||||||
| Inventories |
101 | 11 | ||||||||
| Other financial assets |
D.3 | 134 | 120 | |||||||
| Exploration and evaluation assets |
B.1 | 649 | 807 | |||||||
| Oil and gas properties |
B.2 | 40,927 | 39,919 | |||||||
| Deferred tax assets |
1,680 | 1,959 | ||||||||
| Lease assets |
1,182 | 1,264 | ||||||||
| Investments accounted for using the equity method |
258 | 265 | ||||||||
| Goodwill |
B.4 | 4,669 | 4,614 | |||||||
| Other assets |
378 | 227 | ||||||||
|
|
|
|
|
|||||||
| Total non-current assets |
50,780 | 50,031 | ||||||||
|
|
|
|
|
|||||||
| Total assets |
56,738 | 59,321 | ||||||||
|
|
|
|
|
|||||||
| Current liabilities |
||||||||||
| Payables |
1,934 | 2,094 | ||||||||
| Interest-bearing liabilities |
227 | 260 | ||||||||
| Other financial liabilities |
D.3 | 115 | 654 | |||||||
| Provisions |
D.2 | 1,344 | 1,219 | |||||||
| Tax payable |
725 | 1,854 | ||||||||
| Lease liabilities |
329 | 324 | ||||||||
| Other liabilities |
271 | 203 | ||||||||
|
|
|
|
|
|||||||
| Total current liabilities |
4,945 | 6,608 | ||||||||
|
|
|
|
|
|||||||
| Non-current liabilities |
||||||||||
| Interest-bearing liabilities |
4,882 | 4,878 | ||||||||
| Deferred tax liabilities |
2,222 | 2,457 | ||||||||
| Other financial liabilities |
D.3 | 71 | 67 | |||||||
| Provisions |
D.2 | 5,750 | 5,960 | |||||||
| Tax payable |
38 | 36 | ||||||||
| Lease liabilities |
1,241 | 1,310 | ||||||||
| Other liabilities |
905 | 878 | ||||||||
|
|
|
|
|
|||||||
| Total non-current liabilities |
15,109 | 15,586 | ||||||||
|
|
|
|
|
|||||||
| Total liabilities |
20,054 | 22,194 | ||||||||
|
|
|
|
|
|||||||
| Net assets |
36,684 | 37,127 | ||||||||
|
|
|
|
|
|||||||
| Equity |
||||||||||
| Issued and fully paid shares |
C.1 | 29,001 | 29,001 | |||||||
| Shares reserved for employee share plans |
C.1 | (50 | ) | (38 | ) | |||||
| Other reserves |
6,576 | 4,031 | ||||||||
| Retained earnings |
382 | 3,342 | ||||||||
|
|
|
|
|
|||||||
| Equity attributable to equity holders of the parent |
35,909 | 36,336 | ||||||||
|
|
|
|
|
|||||||
| Non-controlling interest |
775 | 791 | ||||||||
|
|
|
|
|
|||||||
| Total equity |
36,684 | 37,127 | ||||||||
|
|
|
|
|
|||||||
The accompanying notes form part of the half-year financial statements.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 23 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS
for the half-year ended 30 June 2023
| Notes | 2023 US$m |
2022 US$m |
||||||||
| Cash flows from operating activities |
||||||||||
| Profit after tax for the period |
1,766 | 1,679 | ||||||||
| Adjustments for: |
||||||||||
| Non-cash items |
||||||||||
| Depreciation and amortisation |
1,948 | 927 | ||||||||
| Depreciation of lease assets |
81 | 62 | ||||||||
| Change in fair value of derivative financial instruments |
269 | 326 | ||||||||
| Net finance (income)/costs |
(37 | ) | 55 | |||||||
| Tax expense |
1,062 | 1,248 | ||||||||
| Exploration and evaluation written off |
1 | 1 | ||||||||
| Impairment losses |
B.3 | 68 | — | |||||||
| Restoration movement |
20 | 38 | ||||||||
| Gain on disposal of oil and gas properties |
— | (430 | ) | |||||||
| Movement in onerous contracts provision |
— | (245 | ) | |||||||
| Other |
(180 | ) | 18 | |||||||
| Changes in assets and liabilities |
||||||||||
| Decrease/(increase) in trade and other receivables |
488 | (186 | ) | |||||||
| Increase in inventories |
(72 | ) | (39 | ) | ||||||
| Decrease in provisions |
(110 | ) | (43 | ) | ||||||
| Decrease in lease liabilities |
(8 | ) | (24 | ) | ||||||
| Increase in other assets and liabilities |
(234 | ) | (810 | ) | ||||||
| (Decrease)/increase in trade and other payables |
(220 | ) | 314 | |||||||
|
|
|
|
|
|||||||
| Cash generated from operations |
4,842 | 2,891 | ||||||||
| Purchases of shares and payments relating to employee share plans |
(20 | ) | (17 | ) | ||||||
| Interest received |
174 | 17 | ||||||||
| Dividends received |
6 | 14 | ||||||||
| Borrowing costs relating to operating activities |
(8 | ) | (7 | ) | ||||||
| Income tax and PRRT paid |
(2,233 | ) | (322 | ) | ||||||
| Payments for restoration |
(162 | ) | (70 | ) | ||||||
| Receipts from hedge collateral |
332 | — | ||||||||
|
|
|
|
|
|||||||
| Net cash from operating activities |
2,931 | 2,506 | ||||||||
|
|
|
|
|
|||||||
| Cash flows (used in)/from investing activities |
||||||||||
| Cash received on acquisition of BHPP, including cash acquired |
B.4 | — | 1,082 | |||||||
| Payments for capital and exploration expenditure |
(2,457 | ) | (998 | ) | ||||||
| Borrowing costs relating to investing activities |
(181 | ) | (103 | ) | ||||||
| Advances to other external entities |
— | (48 | ) | |||||||
| Proceeds from disposal of non-current assets |
3 | 112 | ||||||||
| Funding of equity accounted investments |
(2 | ) | — | |||||||
|
|
|
|
|
|||||||
| Net cash (used in)/from investing activities |
(2,637 | ) | 45 | |||||||
|
|
|
|
|
|||||||
| Cash flows used in financing activities |
||||||||||
| Repayment of borrowings |
C.2 | (41 | ) | (42 | ) | |||||
| Borrowing costs relating to financing activities |
— | (6 | ) | |||||||
| Repayment of the principal portion of lease liabilities |
(168 | ) | (91 | ) | ||||||
| Borrowing costs relating to lease liabilities |
(3 | ) | (50 | ) | ||||||
| Contributions to non-controlling interests |
(51 | ) | (45 | ) | ||||||
| Dividends paid (net of DRP) |
(2,738 | ) | (717 | ) | ||||||
|
|
|
|
|
|||||||
| Net cash used in financing activities |
(3,001 | ) | (951 | ) | ||||||
|
|
|
|
|
|||||||
| Net (decrease)/increase in cash held |
(2,707 | ) | 1,600 | |||||||
| Cash and cash equivalents at the beginning of the period |
6,201 | 3,025 | ||||||||
|
|
|
|
|
|||||||
| Effects of exchange rate changes |
(25 | ) | (10 | ) | ||||||
|
|
|
|
|
|||||||
| Cash and cash equivalents at the end of the period |
3,469 | 4,615 | ||||||||
|
|
|
|
|
|||||||
The accompanying notes form part of the half-year financial statements.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 24 |
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
For the half-year ended 30 June 2023
| Issued and fully paid shares |
Reserved shares |
Employee benefits reserve |
Foreign currency translation reserve |
Hedging reserve |
Distributable profits reserve |
Other reserve |
Retained earnings |
Equity holders of the parent |
Non-controlling interest |
Total equity |
||||||||||||||||||||||||||||||||||
| Notes |
C.1 US$m |
C.1 US$m |
US$m | US$m | US$m | US$m | US$m | US$m | US$m | US$m | US$m | |||||||||||||||||||||||||||||||||
| At 1 January 2023 |
29,001 | (38 | ) | 278 | 796 | (586 | ) | 3,541 | 2 | 3,342 | 36,336 | 791 | 37,127 | |||||||||||||||||||||||||||||||
| Profit for the period |
— | — | — | — | — | — | — | 1,740 | 1,740 | 26 | 1,766 | |||||||||||||||||||||||||||||||||
| Other comprehensive income/(loss) |
— | — | — | 1 | 578 | — | (23 | ) | — | 556 | — | 556 | ||||||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||||
| Total comprehensive income/(loss) for the period |
— | — | — | 1 | 578 | — | (23 | ) | 1,740 | 2,296 | 26 | 2,322 | ||||||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||||
| Transfers |
— | — | — | — | — | 4,700 | — | (4,700 | ) | — | — | — | ||||||||||||||||||||||||||||||||
| Employee share plan purchases |
— | (20 | ) | — | — | — | — | — | — | (20 | ) | — | (20 | ) | ||||||||||||||||||||||||||||||
| Employee share plan redemptions |
— | 8 | (8 | ) | — | — | — | — | — | — | — | — | ||||||||||||||||||||||||||||||||
| Share-based payments (net of tax) |
— | — | 31 | — | — | — | — | — | 31 | — | 31 | |||||||||||||||||||||||||||||||||
| Dividends paid |
— | — | — | — | — | (2,734 | ) | — | — | (2,734 | ) | (42 | ) | (2,776 | ) | |||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||||
| At 30 June 2023 |
29,001 | (50 | ) | 301 | 797 | (8 | ) | 5,507 | (21 | ) | 382 | 35,909 | 775 | 36,684 | ||||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||||
| At 1 January 2022 |
9,409 | (30 | ) | 232 | 793 | (400 | ) | 58 | — | 3,381 | 13,443 | 786 | 14,229 | |||||||||||||||||||||||||||||||
| Profit for the period |
— | — | — | — | — | — | — | 1,640 | 1,640 | 39 | 1,679 | |||||||||||||||||||||||||||||||||
| Other comprehensive income/(loss) |
— | — | — | 2 | (1,057 | ) | — | 4 | — | (1,051 | ) | — | (1,051 | ) | ||||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||||
| Total comprehensive income/(loss) for the period |
— | — | — | 2 | (1,057 | ) | — | 4 | 1,640 | 589 | 39 | 628 | ||||||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||||
| Transfers |
— | — | — | — | — | 2,025 | — | (2,025 | ) | — | — | — | ||||||||||||||||||||||||||||||||
| Dividend Reinvestment Plan |
332 | — | — | — | — | — | — | — | 332 | — | 332 | |||||||||||||||||||||||||||||||||
| Shares issued for acquisition of BHPP |
19,265 | — | — | — | — | — | — | — | 19,265 | — | 19,265 | |||||||||||||||||||||||||||||||||
| Replacement employee share plan issued on acquisition of BHPP |
— | — | 18 | — | — | — | — | — | 18 | — | 18 | |||||||||||||||||||||||||||||||||
| Employee share plan purchases |
— | (17 | ) | — | — | — | — | — | — | (17 | ) | — | (17 | ) | ||||||||||||||||||||||||||||||
| Employee share plan redemptions |
— | 5 | (5 | ) | — | — | — | — | — | — | — | — | ||||||||||||||||||||||||||||||||
| Share-based payments (net of tax) |
— | — | 27 | — | — | — | — | — | 27 | — | 27 | |||||||||||||||||||||||||||||||||
| Dividends paid |
— | — | — | — | — | — | — | (1,018 | ) | (1,018 | ) | (35 | ) | (1,053 | ) | |||||||||||||||||||||||||||||
| Transaction costs associated with the issue of shares |
(5 | ) | — | — | — | — | — | — | — | (5 | ) | — | (5 | ) | ||||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||||
| At 30 June 2022 |
29,001 | (42 | ) | 272 | 795 | (1,457 | ) | 2,083 | 4 | 1,978 | 32,634 | 790 | 33,424 | |||||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||||
The accompanying notes form part of the half-year financial statements.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 25 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
About these statements
Woodside Energy Group Ltd (Woodside or the Group) is a for-profit entity limited by shares, incorporated and domiciled in Australia. Its shares are publicly traded on the Australian Securities Exchange (ASX), on the Main Market for listed securities of the London Stock Exchange (LSE) (with trades settled in the form of UK Depository Interests) and on the New York Stock Exchange (NYSE) (in the form of Woodside American Depositary Shares). The nature of the operations and principal activities of the Group are described in the Operations, Decommissioning, Marketing and Trading, Projects, Exploration and Development and New Energy and Carbon Solutions sections and in the segment information below.
The condensed consolidated half-year financial statements were authorised for issue in accordance with a resolution of the Directors on 22 August 2023.
Statement of compliance
The condensed consolidated half-year financial statements are condensed general purpose financial statements, which have been prepared in accordance with Australian Accounting Standard (AASB) 134 Interim Financial Reporting as issued by the Australian Accounting Standards Board and the Australian Corporations Act 2001. These condensed consolidated half-year financial statements also comply with International Accounting Standard (IAS) 34 Interim Financial Reporting as issued by the International Accounting Standards Board.
The condensed consolidated half-year financial statements do not include all notes of the type normally included in annual financial statements. Accordingly, these condensed consolidated half-year financial statements are to be read in conjunction with the Financial Statements within the Annual Report for the year ended 31 December 2022 (2022 Financial Statements) and any public announcements made by Woodside during the period ended 30 June 2023 in accordance with the continuous disclosure requirements of the Australian Corporations Act 2001 and the relevant ASX, LSE and NYSE Listing Rules.
The Group’s accounting policies are materially consistent with those disclosed in the Group’s 2022 Financial Statements. Adoption of new or amended standards and interpretations effective 1 January 2023 did not result in any significant changes to the Group’s accounting policies. Refer to Note E.3 for more details.
The significant accounting estimates and judgements are consistent with those disclosed in the 2022 Financial Statements. Estimates have been revised, where required, to reflect current market conditions including the impact of climate change. Updated estimates used for depreciation methodology and asset useful lives, impairment assessments and business combinations are disclosed in Notes B.2, B.3 and B.4 respectively; these assumptions could change in the future. New estimates and judgements relating to the embedded commodity derivative are disclosed in Note D.3.
Currency
The functional and presentation currency of Woodside and all its material subsidiaries is US dollars.
Transactions in foreign currencies are initially recorded in the functional currency of the transacting entity at the exchange rates ruling at the date of transaction. Monetary assets and liabilities denominated in foreign currencies at the reporting date are translated at the rates of exchange ruling at that date. Exchange differences in the consolidated financial statements are taken to the income statement.
Rounding of amounts
The amounts contained in the condensed consolidated half-year financial statements have been rounded to the nearest million dollars under the option available to the Group under Australian Securities and Investments Commission (ASIC) Corporations (Rounding in Financial/Directors’ Reports) Instrument 2016/191 dated 24 March 2016, unless otherwise stated.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 26 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
Basis of preparation
The condensed consolidated half-year financial statements have been prepared on a historical cost basis, except for derivative financial instruments and certain other financial assets and financial liabilities, which have been measured at fair value or amortised cost, adjusted for changes in fair value attributable to the risks that are being hedged in effective hedge relationships. Where not carried at fair value, if the carrying value of financial assets and financial liabilities does not approximate their fair value, the fair value has been included in the notes to the condensed consolidated half-year financial statements.
The condensed consolidated half-year financial statements comprise the financial results of the Group and its subsidiaries for the period ended 30 June 2023. Subsidiaries are fully consolidated from the date on which control is obtained by the Group and cease to be consolidated from the date at which the Group ceases to have control.
The subsidiaries of the Group apply the same reporting period and accounting policies as the parent company in preparation of the condensed consolidated half-year financial statements. All intercompany balances and transactions, including unrealised profits and losses arising from intra-group transactions, have been eliminated in full.
Non-controlling interests are allocated their share of the net profit after tax in the consolidated income statement; their share of other comprehensive income, net of tax, in the consolidated statement of comprehensive income; and are presented within equity in the consolidated statement of financial position, separately from parent shareholders’ equity.
Comparative information
The condensed consolidated half-year financial statements provide comparative information in respect of the previous period. Where required, a reclassification of items in the financial statements of the previous period has been made in accordance with the classification of items in the condensed consolidated half-year financial statements of the current period.
Reporting segments
Refer to the 2022 Financial Statements for details of the Group’s operating segment information.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 27 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
A. Earnings for the period
A.1 Segment revenue and expenses
| Australia | International | Marketing | Corporate/ Other |
Consolidated | ||||||||||||||||||||||||||||||||||||
| 2023 US$m |
2022 US$m |
2023 US$m |
2022 US$m |
2023 US$m |
2022 US$m |
2023 US$m |
2022 US$m |
2023 US$m |
2022 US$m |
|||||||||||||||||||||||||||||||
| Liquified natural gas |
3,894 | 3,119 | — | — | 785 | 986 | — | — | 4,679 | 4,105 | ||||||||||||||||||||||||||||||
| Pipeline gas |
515 | 232 | 198 | 57 | — | — | — | — | 713 | 289 | ||||||||||||||||||||||||||||||
| Crude oil and condensate |
715 | 1,066 | 1,028 | 243 | 15 | — | — | — | 1,758 | 1,309 | ||||||||||||||||||||||||||||||
| Natural gas liquids |
120 | 11 | 16 | 5 | 23 | — | — | — | 159 | 16 | ||||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
| Revenue from sale of hydrocarbons |
5,244 | 4,428 | 1,242 | 305 | 823 | 986 | — | — | 7,309 | 5,719 | ||||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
| Intersegment revenue1 |
(120 | ) | (323 | ) | (6 | ) | — | 126 | 323 | — | — | — | — | |||||||||||||||||||||||||||
| Processing and services revenue |
85 | 77 | — | — | — | — | — | — | 85 | 77 | ||||||||||||||||||||||||||||||
| Shipping and other revenue |
— | 6 | — | — | 6 | 8 | — | — | 6 | 14 | ||||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
| Other revenue |
(35 | ) | (240 | ) | (6 | ) | — | 132 | 331 | — | — | 91 | 91 | |||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
| Operating revenue2 |
5,209 | 4,188 | 1,236 | 305 | 955 | 1,317 | — | — | 7,400 | 5,810 | ||||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
| Production costs |
(614 | ) | (350 | ) | (193 | ) | (33 | ) | — | — | — | (14 | ) | (807 | ) | (397 | ) | |||||||||||||||||||||||
| Royalties, excise and levies |
(285 | ) | (189 | ) | (31 | ) | (14 | ) | — | — | — | (17 | ) | (316 | ) | (220 | ) | |||||||||||||||||||||||
| Insurance |
(20 | ) | (18 | ) | (5 | ) | (1 | ) | — | — | (9 | ) | (3 | ) | (34 | ) | (22 | ) | ||||||||||||||||||||||
| Inventory movement |
31 | 15 | 2 | — | — | — | — | — | 33 | 15 | ||||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
| Costs of production |
(888 | ) | (542 | ) | (227 | ) | (48 | ) | — | — | (9 | ) | (34 | ) | (1,124 | ) | (624 | ) | ||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
| Land and buildings |
(31 | ) | (25 | ) | (2 | ) | — | — | — | — | — | (33 | ) | (25 | ) | |||||||||||||||||||||||||
| Transferred exploration and evaluation |
(51 | ) | (50 | ) | (2 | ) | (1 | ) | — | — | — | — | (53 | ) | (51 | ) | ||||||||||||||||||||||||
| Plant and equipment |
(1,298 | ) | (774 | ) | (543 | ) | (58 | ) | — | — | (17 | ) | (16 | ) | (1,858 | ) | (848 | ) | ||||||||||||||||||||||
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| Oil and gas properties depreciation and amortisation |
(1,380 | ) | (849 | ) | (547 | ) | (59 | ) | — | — | (17 | ) | (16 | ) | (1,944 | ) | (924 | ) | ||||||||||||||||||||||
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| Shipping and direct sales costs |
(107 | ) | (92 | ) | (38 | ) | (4 | ) | (30 | ) | (15 | ) | — | 17 | (175 | ) | (94 | ) | ||||||||||||||||||||||
| Trading costs |
(4 | ) | — | — | — | (618 | ) | (790 | ) | — | — | (622 | ) | (790 | ) | |||||||||||||||||||||||||
| Other hydrocarbon costs |
(7 | ) | (19 | ) | — | — | — | — | — | — | (7 | ) | (19 | ) | ||||||||||||||||||||||||||
| Other cost of sales |
— | (3 | ) | — | — | — | — | — | — | — | (3 | ) | ||||||||||||||||||||||||||||
| Movement in onerous contract provision3 |
— | — | — | — | — | 216 | — | — | — | 216 | ||||||||||||||||||||||||||||||
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| Other cost of sales |
(118 | ) | (114 | ) | (38 | ) | (4 | ) | (648 | ) | (589 | ) | — | 17 | (804 | ) | (690 | ) | ||||||||||||||||||||||
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| Cost of sales |
(2,386 | ) | (1,505 | ) | (812 | ) | (111 | ) | (648 | ) | (589 | ) | (26 | ) | (33 | ) | (3,872 | ) | (2,238 | ) | ||||||||||||||||||||
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| Gross profit |
2,823 | 2,683 | 424 | 194 | 307 | 728 | (26 | ) | (33 | ) | 3,528 | 3,572 | ||||||||||||||||||||||||||||
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| Other income4 |
106 | 489 | — | 4 | 1 | 5 | 27 | — | 134 | 498 | ||||||||||||||||||||||||||||||
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| Exploration and evaluation expenditure |
(9 | ) | (7 | ) | (123 | ) | (19 | ) | — | — | (1 | ) | (14 | ) | (133 | ) | (40 | ) | ||||||||||||||||||||||
| Amortisation of permit acquisitions |
— | — | (4 | ) | (3 | ) | — | — | — | — | (4 | ) | (3 | ) | ||||||||||||||||||||||||||
| Write-offs |
— | — | (1 | ) | (1 | ) | — | — | — | — | (1 | ) | (1 | ) | ||||||||||||||||||||||||||
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| Exploration and evaluation |
(9 | ) | (7 | ) | (128 | ) | (23 | ) | — | — | (1 | ) | (14 | ) | (138 | ) | (44 | ) | ||||||||||||||||||||||
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| General, administration and other costs5 |
— | (5 | ) | (3 | ) | (12 | ) | (10 | ) | — | (224 | ) | (525 | ) | (237 | ) | (542 | ) | ||||||||||||||||||||||
| Depreciation of lease assets |
(22 | ) | (21 | ) | (7 | ) | (1 | ) | (34 | ) | — | (18 | ) | (40 | ) | (81 | ) | (62 | ) | |||||||||||||||||||||
| Restoration movement |
(8 | ) | (31 | ) | (12 | ) | (10 | ) | — | — | — | 3 | (20 | ) | (38 | ) | ||||||||||||||||||||||||
| Other6 |
(27 | ) | (13 | ) | (1 | ) | (64 | ) | (99 | ) | (227 | ) | (200 | ) | (98 | ) | (327 | ) | (402 | ) | ||||||||||||||||||||
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| Other costs |
(57 | ) | (70 | ) | (23 | ) | (87 | ) | (143 | ) | (227 | ) | (442 | ) | (660 | ) | (665 | ) | (1,044 | ) | ||||||||||||||||||||
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| Other expenses |
(66 | ) | (77 | ) | (151 | ) | (110 | ) | (143 | ) | (227 | ) | (443 | ) | (674 | ) | (803 | ) | (1,088 | ) | ||||||||||||||||||||
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| Impairment losses7 |
(68 | ) | — | — | — | — | — | — | — | (68 | ) | — | ||||||||||||||||||||||||||||
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| Profit/(loss) before tax and net finance costs |
2,795 | 3,095 | 273 | 88 | 165 | 506 | (442 | ) | (707 | ) | 2,791 | 2,982 | ||||||||||||||||||||||||||||
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| 1. | Intersegment revenue comprises the incremental income net of all incremental associated expenses generated by the Marketing segment’s optimisation of the oil and gas portfolio. |
| 2. | Operating revenue includes revenue from contracts with customers of $7,394 million (2022: $5,802 million) and sub-lease income of $6 million (2022: $8 million) disclosed within shipping and other revenue. |
| 3. | The 2022 movement comprised changes in estimates of $245 million offset by provisions used of $29 million. |
| 4. | Includes fees and recoveries and other income not associated with the ongoing operations of the business. The 2022 amount includes the gain on Train 2 sell-down of $427 million. |
| 5. | Transaction costs incurred as a result of the BHPP merger on 1 June 2022 were included in the Corporate/Other segment in 2022. |
| 6. | Includes losses on hedging activities, fair value losses on the embedded derivatives and other expenses not associated with the ongoing operations of the business. |
| 7. | Impairment losses on oil and gas properties. Refer to Note B.3 for more details. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 28 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
A.2 Finance costs
| 2023 US$m |
2022 US$m |
|||||||
| Interest on interest-bearing liabilities |
112 | 101 | ||||||
| Interest on lease liabilities |
54 | 58 | ||||||
| Accretion charge |
134 | 26 | ||||||
| Other finance costs |
21 | 14 | ||||||
| Less: Finance costs capitalised against qualifying assets |
(184 | ) | (113 | ) | ||||
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| 137 | 86 | |||||||
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A.3 Dividends paid and proposed
Woodside Energy Group Ltd, the parent entity, paid and proposed dividends as set out below:
| 2023 US$m |
2022 US$m |
|||||||
| (a) Dividends paid during the financial period Prior year fully franked final dividend US$1.44, paid on 5 April 2023 (2022: US$1.05, paid on 23 March 2022) |
2,734 | 1,018 | ||||||
| (b) Dividend declared subsequent to the reporting period (not recorded as a liability) Current year fully franked interim dividend US$0.80 to be paid on 28 September 2023 (2022: US$1.09, paid on 6 October 2022) |
1,519 | 2,070 | ||||||
A.4 Earnings per share
| 2023 | 2022 | |||||||
| Profit attributable to equity holders of the parent (US$m) |
1,740 | 1,640 | ||||||
| Weighted average number of shares on issue for basic earnings per share |
1,896,624,636 | 1,127,109,476 | ||||||
| Effect of dilution from contingently issuable shares |
12,981,487 | 11,895,577 | ||||||
| Weighted average number of shares on issue adjusted for the effect of dilution |
1,909,606,123 | 1,139,005,053 | ||||||
| Basic earnings per share (US cents) |
91.7 | 145.5 | ||||||
| Diluted earnings per share (US cents) |
91.1 | 144.0 | ||||||
Earnings per share is calculated by dividing the profit for the period attributable to ordinary equity holders of the parent by the weighted average number of shares on issue during the period. The weighted average number of shares makes allowance for shares reserved for employee share plans. Diluted earnings per share is calculated by adjusting basic earnings per share by the number of ordinary shares that would be issued on conversion of all the dilutive potential ordinary shares into ordinary shares. As at 30 June 2023, 12,981,487 (2022: 11,895,577) awards granted under the Woodside employee share plans are considered dilutive.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 29 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
A.5 Taxes
| 2023 US$m |
2022 US$m |
|||||||
| (a) Reconciliation of income tax expense |
||||||||
| Profit before tax |
2,828 | 2,927 | ||||||
| Petroleum resource rent tax (PRRT) expense |
(778 | ) | (424 | ) | ||||
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|
|
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| Profit before income tax |
2,050 | 2,503 | ||||||
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|
|||||
| Income tax expense calculated at 30% |
615 | 751 | ||||||
| Effect of tax rate differentials |
30 | (64 | ) | |||||
| Effect of deferred tax assets not recognised |
67 | 33 | ||||||
| Effect of tax losses and credits previously unrecognised1 |
(340 | ) | (25 | ) | ||||
| Foreign exchange impact on tax benefit |
(83 | ) | — | |||||
| Adjustment to prior years |
(16 | ) | (50 | ) | ||||
| Integration and transaction costs non-deductible1 |
— | 148 | ||||||
| Other |
11 | 31 | ||||||
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|
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| Income tax expense |
284 | 824 | ||||||
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| 2023 % |
2022 % |
|||||||
| (b) Effective income tax rate: Australian and global operations2 |
||||||||
| Effective income tax rate1 |
||||||||
| Australia |
30.2 | 35.1 | ||||||
| Global |
13.9 | 32.9 | ||||||
| 1. | As a result of the FID to develop the Trion resource in 2023, the Group has recognised deferred tax assets of $319 million, resulting in a reduction of the global effective income tax rate from 29.6% to 13.9%. The Group incurred certain transaction costs for the half-year ended 30 June 2022 associated to the merger with BHPP which were deemed non-deductible, which had the effect of increasing the global effective income tax rate from 27.0% to 32.9%. |
| 2. | The global operations effective income tax rate (ETR) is calculated as the Group’s income tax expense divided by profit before income tax. The Australian operations ETR is calculated with reference to all Australian companies and excludes foreign exchange on settlement and revaluation of income tax liabilities. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 30 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
B. Production and growth assets
B.1 Exploration and evaluation
| Asia Pacific US$m |
Americas US$m |
Africa US$m |
Total US$m |
|||||||||||||
| Half-year ended 30 June 2023 |
||||||||||||||||
| Carrying amount at 1 January 2023 |
529 | 240 | 38 | 807 | ||||||||||||
| Additions |
16 | 111 | 3 | 130 | ||||||||||||
| Amortisation of licence acquisition costs |
— | (3 | ) | (1 | ) | (4 | ) | |||||||||
| Expensed |
— | (1 | ) | — | (1 | ) | ||||||||||
| Transferred exploration and evaluation1 |
(9 | ) | (274 | ) | — | (283 | ) | |||||||||
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| Carrying amount at 30 June 2023 |
536 | 73 | 40 | 649 | ||||||||||||
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| Year ended 31 December 2022 |
||||||||||||||||
| Carrying amount at 1 January 2022 |
546 | — | 68 | 614 | ||||||||||||
| Acquisitions through business combination2 |
— | 180 | — | 180 | ||||||||||||
| Additions |
19 | 204 | 17 | 240 | ||||||||||||
| Disposals |
— | (10 | ) | — | (10 | ) | ||||||||||
| Amortisation of licence acquisition costs |
— | (8 | ) | (2 | ) | (10 | ) | |||||||||
| Expensed3 |
— | (126 | ) | (45 | ) | (171 | ) | |||||||||
| Transferred exploration and evaluation |
(36 | ) | — | — | (36 | ) | ||||||||||
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| Carrying amount at 31 December 2022 |
529 | 240 | 38 | 807 | ||||||||||||
|
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| 1. | On 20 June 2023, the Group made a final investment decision to develop the Trion resource in Mexico. Related exploration and evaluation assets were transferred to oil and gas properties. |
| 2. | Refer to Note B.4 for details of business combination. |
| 3. | For the year ended 31 December 2022, $125 million relates to costs of unsuccessful wells. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 31 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
B.2 Oil and gas properties
| Land and buildings US$m |
Transferred exploration and evaluation US$m |
Plant and equipment US$m |
Projects in development5 US$m |
Total US$m |
||||||||||||||||
| Half-year ended 30 June 2023 |
||||||||||||||||||||
| Carrying amount at 1 January 2023 |
840 | 481 | 23,057 | 15,541 | 39,919 | |||||||||||||||
| Additions1 |
— | — | (111 | ) | 2,852 | 2,741 | ||||||||||||||
| Disposals at written down value |
(3 | ) | — | (1 | ) | — | (4 | ) | ||||||||||||
| Depreciation and amortisation |
(33 | ) | (53 | ) | (1,858 | ) | — | (1,944 | ) | |||||||||||
| Impairment losses2 |
— | — | (68 | ) | — | (68 | ) | |||||||||||||
| Completions and transfers |
— | 156 | 1,828 | (1,701 | ) | 283 | ||||||||||||||
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|||||||||||
| Carrying amount at 30 June 2023 |
804 | 584 | 22,847 | 16,692 | 40,927 | |||||||||||||||
|
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|||||||||||
| At 30 June 2023 |
||||||||||||||||||||
| Historical cost |
1,760 | 1,694 | 46,977 | 17,088 | 67,519 | |||||||||||||||
| Accumulated depreciation and impairment |
(956 | ) | (1,110 | ) | (24,130 | ) | (396 | ) | (26,592 | ) | ||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net carrying amount |
804 | 584 | 22,847 | 16,692 | 40,927 | |||||||||||||||
|
|
|
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|
|
|
|
|
|
|
|||||||||||
| Year ended 31 December 2022 |
||||||||||||||||||||
| Carrying amount at 1 January 2022 |
739 | 526 | 12,465 | 4,919 | 18,649 | |||||||||||||||
| Acquisitions through business combination3 |
64 | — | 11,952 | 7,337 | 19,353 | |||||||||||||||
| Additions4 |
— | — | (508 | ) | 4,332 | 3,824 | ||||||||||||||
| Disposals at written down value |
(3 | ) | (10 | ) | (32 | ) | — | (45 | ) | |||||||||||
| Depreciation and amortisation |
(54 | ) | (107 | ) | (2,637 | ) | — | (2,798 | ) | |||||||||||
| Impairment reversals |
87 | 30 | 783 | — | 900 | |||||||||||||||
| Completions and transfers |
7 | 42 | 1,034 | (1,047 | ) | 36 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Carrying amount at 31 December 2022 |
840 | 481 | 23,057 | 15,541 | 39,919 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| At 31 December 2022 |
||||||||||||||||||||
| Historical cost |
1,765 | 1,538 | 45,273 | 15,937 | 64,513 | |||||||||||||||
| Accumulated depreciation and impairment |
(925 | ) | (1,057 | ) | (22,216 | ) | (396 | ) | (24,594 | ) | ||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net carrying amount |
840 | 481 | 23,057 | 15,541 | 39,919 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
The Group has capital expenditure commitments contracted for, but not provided for in the financial statements, of$6,027 million (revised 31 December 20226: $6,469 million).
| 1. | Includes $2,555 million of capital additions, $184 million of capitalised borrowing costs and changes in restoration provision assumptions resulting in $113 million of additions to projects in development offset by $111 million within plant and equipment. |
| 2. | Refer to Note B.3 for details on impairment losses. |
| 3. | Refer to Note B.4 for details of business combination. |
| 4. | Includes $3,904 million of capital additions and $294 million of capitalised borrowing costs offset by $374 million following changes in restoration provision assumptions. |
| 5. | Projects in development include the fair value ascribed to future phases of certain projects acquired through business combinations. |
| 6. | The 2022 Financial Statements disclosed capital expenditure commitments of $7,762 million which duplicated certain amounts post-merger. This has now been revised to reflect the Group’s share of commitments. |
Change in depreciation methodology and asset useful lives
The Group has undertaken a review of the depreciation methodology and asset useful lives for oil and gas properties in accordance with its accounting policies and the accounting standards, considering the scale and diversity of the post-merger portfolio.
In assessing useful lives of certain oil and gas assets, these have been determined with reference to either their proved (1P) or proved plus probable (2P) reserves, which is then used in the units of production depreciation calculation.
From 1 January 2023, upstream oil and conventional gas assets have been depreciated over proved reserves (previously proved plus probable, except for certain assets considered late life). Upstream LNG assets has continued to be depreciated over proved plus probable reserves. Multi-product assets are assessed on a case-by-case basis and aligned to the most appropriate representation of useful life.
The changes in depreciation methodology and asset useful lives have been applied from 1 January 2023, resulting in an increase in depreciation expense of $190 million for the half-year ended 30 June 2023.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 32 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
B.3 Impairment of exploration and evaluation and oil and gas properties
Impairment of non-current assets
The policy for impairment testing and methods used to determine recoverable amounts are consistent with the disclosure in Note B.4 of the 2022 Financial Statements. The recoverable amount of an asset or cash-generating unit (CGU) is determined as the higher of its value in use (VIU) and fair value less cost of disposal (FVLCD). Oil and gas properties are typically tested at the CGU level. Exploration and evaluation assets, where applicable, are assessed at the area of interest (AOI) level using FVLCD as there is no VIU. Upon FID, impairment testing is performed on the asset prior to the transfer from exploration and evaluation assets to oil and gas properties. Goodwill is tested for impairment at least annually and more frequently if events or changes in circumstances indicate that it might be impaired. For the half-year ended 30 June 2023, there have been no such events or changes in circumstances to indicate that goodwill may be impaired.
Recognised impairment
As at 30 June 2023, the Group assessed each AOI and CGU to determine whether an indicator of impairment or impairment reversal existed. The Group identified the following indicators of impairment on CGUs where an impairment loss has been recognised:
| - | Pyrenees CGU – Reduction in future production volumes, reflecting a lower-than-expected outcome of drilling activities. |
An impairment was recognised for the Pyrenees CGU (refer to Note A.1). The result was as follows:
| Impairment loss | ||||||||||||||
| Oil and gas properties | ||||||||||||||
| Segment |
CGU |
Recoverable Amount US$m |
Plant and equipment US$m |
Total US$m |
||||||||||
| Australia |
Pyrenees | 159 | 68 | 68 | ||||||||||
The recoverable amount has been determined using the FVLCD method using discounted cash flow projections, classified as Level 3 on the fair value hierarchy. The carrying amount of the CGU includes all relevant assets allocated to the respective CGU.
Management considers there to be no reasonably possible change in the respective key estimates and judgements which, in isolation, would result in a material adjustment to the carrying amount of the Pyrenees CGU.
Key estimates and judgements
With the exception of Brent oil price estimates, key assumptions and judgements used have not materially changed from those disclosed in Note B.4 in the 2022 Financial Statements.
The nominal Brent oil prices (US$/bbl) used were:
| 2023 | 2024 | 2025 | 2026 | 2027 | 2028 | |||||||||||||||||||
| 30 June 20231 |
82 | 78 | 74 | 76 | 77 | 79 | ||||||||||||||||||
| 1. | Based on US$70/bbl (2022 real terms) from 2025 with prices escalated at 2.0% annually thereafter. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 33 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
B.4 Business combination
BHP Petroleum merger
Refer to the 2022 Financial Statements for details of the BHP Petroleum (BHPP) merger. Except for changes noted below, the disclosures are consistent with Note B.5 of the 2022 Financial Statements.
On 1 June 2022, the Group acquired 100% of the issued share capital of BHP Petroleum International Pty Ltd (subsequently renamed Woodside Energy Global Holdings Pty Ltd), which held BHP Group’s (BHP) oil and gas business. In exchange, the Group issued 914,768,948 new Woodside shares to BHP as part of the merger consideration. The transaction was accounted for as a business combination with an acquisition date of 1 June 2022. The Group had 12 months from the acquisition date to make adjustments to the fair value of net identifiable assets acquired and the resultant value of goodwill. As at 30 June 2023, the Group has finalised the purchase price allocation which has resulted in goodwill of $4,669 million, a net increase of $55 million from the provisional amount reported at 31 December 2022.
Details of the purchase consideration and the fair value of goodwill, identifiable assets and liabilities of BHPP acquired are as follows:
| Fair value of net identifiable assets and goodwill arising on acquisition date |
US$m | |||
| Cash and cash equivalents |
399 | |||
| Receivables |
1,164 | |||
| Inventories |
295 | |||
| Investments accounted for using the equity method |
267 | |||
| Other financial assets |
59 | |||
| Other assets |
284 | |||
| Exploration and evaluation assets |
180 | |||
| Oil and gas properties |
19,353 | |||
| Lease assets |
142 | |||
| Payables |
(1,035 | ) | ||
| Provisions |
(4,827 | ) | ||
| Tax payable |
(365 | ) | ||
| Deferred tax liabilities |
(653 | ) | ||
| Lease liabilities |
(268 | ) | ||
| Other liabilities |
(1,054 | ) | ||
|
|
|
|||
| Net identifiable assets acquired |
13,941 | |||
|
|
|
|||
| Goodwill arising on acquisition |
4,669 | |||
|
|
|
|||
| Purchase consideration |
18,610 | |||
|
|
|
|||
| Purchase consideration |
US$m | |||
| Shares issued, at fair value |
19,265 | |||
| Other reserves (Share replacement awards) |
18 | |||
| Locked box payment received1 |
(683 | ) | ||
| Finalisation adjustment to locked box payment received |
10 | |||
|
|
|
|||
| Total purchase consideration |
18,610 | |||
|
|
|
|||
| 1. | Represents the positive net cash flow of $1,513 million generated by BHPP assets from the effective date of the business combination offset by the notional dividend distribution of $830 million paid to BHP. |
| Analysis of cash flows on acquisition |
US$m | |||
| Cash acquired on acquisition |
399 | |||
| Locked box payment received |
683 | |||
|
|
|
|||
| Net cash flow received on acquisition |
1,082 | |||
|
|
|
|||
| Woodside Energy Group Ltd | Half-Year Report 2023 | 34 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
B.4 Business combination (continued)
Shares issued, at fair value
The fair value of 914,768,948 shares issued as part of the consideration paid to BHP was $19,265 million. This was based on the published share price on 1 June 2022 of US$21.06 per share.
Locked box payment received
For the year ended 31 December 2022, the Group received $683 million as part of the merger consideration which includes the locked box payment of $1,513 million representing the positive net cash flow generated by BHPP assets from the effective date of the transaction to completion date offset by the notional dividend distribution of $830 million paid to BHP. The initial purchase consideration was subsequently adjusted by $10 million against the locked box payment received.
Goodwill
Goodwill arising from the acquisition has been recognised as the excess of consideration paid above the fair value of the assets acquired and liabilities assumed as part of the business combination. $2,035 million of the goodwill arises from the deferred tax liability recognised on acquisition as a consequence of asset tax bases received in the merger being lower than the fair value of the assets acquired. The remaining goodwill of $2,634 million reflects the value expected to be generated from the Pluto-Scarborough CGU as a result of the merger. The goodwill is not deductible for tax purposes.
Key estimates and judgements
| (a) | Fair value determination for net assets acquired |
Judgement is required to determine the fair value of assets acquired and liabilities assumed in a business combination, which can have a material impact on resultant goodwill. This includes the use of a cash flow model to estimate the expected future cash flows of the oil and gas assets acquired, based on reserves and resources at acquisition date and the discount rate used. The expected future cash flows are based on estimates of future production, commodity and carbon prices, operating costs, and forecast capital expenditures at acquisition date.
Restoration provisions require judgmental assumptions regarding removal date, environmental legislation and regulations and the extent of restoration activities required in determining the cost estimate.
Carry forward tax losses are recognised only if it is probable that sufficient future taxable income will be available to utilise the losses.
| (b) | Goodwill allocation |
Judgement is required in the allocation of goodwill to the Group’s cash-generating units that are expected to benefit from the synergies of the business combination.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 35 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
C. Debt and capital
C.1 Contributed equity
| Issued and fully paid shares |
Number of shares |
US$m | ||||||
| Half-year ended 30 June 2023 |
||||||||
| Opening balance |
1,898,749,771 | 29,001 | ||||||
|
|
|
|
|
|||||
| Amounts as at 30 June 2023 |
1,898,749,771 | 29,001 | ||||||
|
|
|
|
|
|||||
| Year ended 31 December 2022 |
||||||||
| Opening balance |
969,631,826 | 9,409 | ||||||
| DRP – ordinary shares issued at US$23.14 (2021 final dividend) |
14,348,997 | 332 | ||||||
| Ordinary shares issued at US$21.06 for the acquisition of BHPP1 |
914,768,948 | 19,265 | ||||||
| DRP – ordinary shares issued at US$14.21 (2021 interim dividend) |
— | (5 | ) | |||||
|
|
|
|
|
|||||
| Amounts as at 31 December 2022 |
1,898,749,771 | 29,001 | ||||||
|
|
|
|
|
|||||
| 1. | 914,768,948 new Woodside shares were issued as consideration for the BHPP merger. Refer to Note B.4 for details. |
All shares are a single class with equal rights to dividends, capital distributions and voting. The Company does not have authorised capital nor par value in respect of its issued shares.
| Reserved shares |
30 June 2023 US$m |
31 December 2022 US$m |
||||||
| 2,268,409 (2022: 1,873,777) reserved shares |
(50 | ) | (38 | ) | ||||
|
|
|
|
|
|||||
C.2 Interest-bearing liabilities and financing facilities
During the period, the Group repaid $41 million of the Japan Bank for International Cooperation (JBIC) facility. There were no other material changes to interest-bearing liabilities and financing facilities. For the year ended 31 December 2022, the Group repaid $200 million of the Yucho 2022 Medium Term Note and $83 million of the JBIC facility.
Fair value
The carrying amounts of interest-bearing liabilities approximate their fair values, with the exception of the Group’s unsecured bonds and the medium-term notes. The unsecured bonds have a carrying amount of $4,086 million (31 December 2022: $4,084 million) and a fair value of $3,882 million (31 December 2022: $3,852 million). The medium-term notes have a carrying amount of $393 million (31 December 2022: $385 million) and a fair value of $382 million (31 December 2022: $372 million). Fair value is calculated based on the present value of future principal and interest cash flows, discounted at the market rate of interest at the reporting date and classified as Level 1 on the fair value hierarchy.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 36 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
D. Other assets and liabilities
D.1 Segment assets and liabilities
| 30 June 2023 US$m |
31 December 2022 US$m |
|||||||
| (a) Segment assets |
||||||||
| Australia |
30,707 | 31,240 | ||||||
| International |
18,925 | 18,084 | ||||||
| Marketing1 |
709 | 182 | ||||||
| Corporate/Other1 |
6,397 | 9,815 | ||||||
|
|
|
|
|
|||||
| 56,738 | 59,321 | |||||||
|
|
|
|
|
|||||
| 30 June 2023 US$m |
31 December 2022 US$m |
|||||||
| (b) Segment liabilities |
||||||||
| Australia2 |
7,170 | 7,552 | ||||||
| International |
2,695 | 2,677 | ||||||
| Marketing1 |
752 | 561 | ||||||
| Corporate/Other1,2 |
9,437 | 11,404 | ||||||
|
|
|
|
|
|||||
| 20,054 | 22,194 | |||||||
|
|
|
|
|
|||||
| 1. | In 2023, certain shipping activities are now undertaken by the Marketing segment. As a result of this change, $477 million of lease assets and $624 million of lease liabilities are now reported within the Marketing segment as at 30 June 2023. The impact of this change on revenue and expenses is not material. |
| 2. | 2022 comparatives have been revised to reflect the appropriate allocation of intercompany liabilities between Australia and Corporate/Other segments post-merger. As a result of this change, $552 million has been reclassified to the Corporate/Other segment. |
Corporate/other assets mainly comprise cash and cash equivalents, lease assets and deferred tax assets. Corporate/other liabilities mainly comprise interest bearing liabilities, lease liabilities and deferred tax liabilities.
D.2 Provisions
| Restoration1 US$m |
Employee benefits US$m |
Onerous contracts US$m |
Other US$m |
Total US$m |
||||||||||||||||
| Half-year ended 30 June 2023 |
||||||||||||||||||||
| At 1 January 2023 |
6,253 | 517 | — | 409 | 7,179 | |||||||||||||||
| Change in provision |
(138 | ) | (54 | ) | — | (9 | ) | (201 | ) | |||||||||||
| Unwinding of present value discount |
116 | — | — | — | 116 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Carrying amount at 30 June 2023 |
6,231 | 463 | — | 400 | 7,094 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Current |
765 | 274 | — | 305 | 1,344 | |||||||||||||||
| Non-current |
5,466 | 189 | — | 95 | 5,750 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net carrying amount |
6,231 | 463 | — | 400 | 7,094 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Year ended 31 December 2022 |
||||||||||||||||||||
| At 1 January 2022 |
2,218 | 286 | 214 | 106 | 2,824 | |||||||||||||||
| Acquisitions through business combination2 |
4,310 | 329 | — | 165 | 4,804 | |||||||||||||||
| Change in provision |
(382 | ) | (98 | ) | (216 | ) | 137 | (559 | ) | |||||||||||
| Unwinding of present value discount |
107 | — | 2 | 1 | 110 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Carrying amount at 31 December 2022 |
6,253 | 517 | — | 409 | 7,179 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Current |
575 | 331 | — | 313 | 1,219 | |||||||||||||||
| Non-current |
5,678 | 186 | — | 96 | 5,960 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net carrying amount |
6,253 | 517 | — | 409 | 7,179 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 1. | 2023 change in provision is due to a revision of discount rates of $86 million (primarily due to an increase in risk free rates) and provisions used of $162 million, offset by changes in estimates of $110 million. |
| 2. | Refer to Note B.4 for details of business combination. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 37 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
D.3 Other financial assets and liabilities
| 30 June 2023 US$m |
31 December 2022 US$m |
|||||||
| Other financial assets |
||||||||
| Financial instruments at fair value through profit and loss |
||||||||
| Derivative financial instruments designated as hedges |
221 | 207 | ||||||
| Other financial assets |
50 | 22 | ||||||
| Financial instruments at amortised cost |
||||||||
| Hedge collateral (including interest) |
177 | 509 | ||||||
| Other financial assets |
30 | 30 | ||||||
| Financial instruments at fair value through other comprehensive income |
||||||||
| Other financial assets |
29 | 29 | ||||||
|
|
|
|
|
|||||
| Total other financial assets |
507 | 797 | ||||||
|
|
|
|
|
|||||
| Current |
373 | 677 | ||||||
| Non-current |
134 | 120 | ||||||
|
|
|
|
|
|||||
| Net carrying amount |
507 | 797 | ||||||
|
|
|
|
|
|||||
| Other financial liabilities |
||||||||
| Financial instruments at fair value through profit and loss |
||||||||
| Derivative financial instruments designated as hedges |
129 | 721 | ||||||
| Embedded derivative |
52 | — | ||||||
| Other financial liabilities |
5 | — | ||||||
|
|
|
|
|
|||||
| Total other financial liabilities |
186 | 721 | ||||||
|
|
|
|
|
|||||
| Current |
115 | 654 | ||||||
| Non-current |
71 | 67 | ||||||
|
|
|
|
|
|||||
| Net carrying amount |
186 | 721 | ||||||
|
|
|
|
|
|||||
Hedging activities
During the period, the following hedging activities were undertaken:
| • | The Group hedged a percentage of its oil-linked exposure, entering into oil swap derivatives settling in 2023 and 2024 in order to achieve minimum average sales prices of $75 per barrel. |
| • | Through foreign exchange forward contracts, the Group hedged the Australian dollar to US dollar exchange rate for a portion of the Australian dollar denominated capital expenditure expected to be incurred for the Scarborough development. |
| • | In 2022, the Group voluntarily placed $506 million (excluding interest) as collateral against the oil hedge positions to reduce counterparty credit risk exposure. The Group has subsequently received $332 million (excluding interest) of the collateral in 2023. The collateral will continue to mature in line with cargoes delivering up to August 2023. |
The following table presents the Group’s derivative financial instruments designated as hedges, measured and recognised at fair value:
| 30 June 2023 US$m |
31 December 2022 US$m |
|||||||
| Oil swaps (cash flow hedges) |
20 | (114 | ) | |||||
| HH Corpus Christi commodity swaps (cash flow hedges) |
(27 | ) | 26 | |||||
| TTF Corpus Christi commodity swaps (cash flow hedges) |
48 | (469 | ) | |||||
| Interest rate swaps (cash flow hedges) |
59 | 55 | ||||||
| Cross-currency interest rate swaps (cash flow and fair value hedges) |
14 | 5 | ||||||
| FX forwards (cash flow hedges) |
(22 | ) | (17 | ) | ||||
|
|
|
|
|
|||||
| Total derivative financial instruments asset/(liability) designated as hedges |
92 | (514 | ) | |||||
|
|
|
|
|
|||||
| Woodside Energy Group Ltd | Half-Year Report 2023 | 38 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
D.3 Other financial assets and liabilities (continued)
Embedded commodity derivative
In 2023, the Group entered into a revised long-term gas sale and purchase contract (GSPA) with Perdaman with conditions precedent being satisfied during the half-year, where a component of the selling price is linked to the price of Urea. The contract has been assessed to contain an embedded commodity derivative that is required to be separated and recognised at fair value through profit and loss. The carrying value of the embedded derivative at 30 June 2023 amounted to a liability of $52 million (31 December 2022: nil). The derivative is remeasured to fair value at each reporting date in accordance with the Urea price at that date. As at 30 June 2023, the unrealised loss of $52 million has been recognised through profit and loss.
Interest rate benchmark reform
A fundamental reform of major interest rate benchmarks is being undertaken globally, including the replacement of some interbank offered rates (IBORs) with alternative nearly risk-free rates (referred to as ‘IBOR reform’). The Group has exposures to IBORs on its financial instruments that will be impacted as part of these market-wide initiatives. The Group’s main IBOR exposure at the reporting date is USD LIBOR. In 2020, the Federal Reserve announced that the three-month and six-month USD LIBOR will be phased out and eventually replaced by June 2023.
During the period, the Group has transitioned the majority of its financial liabilities from USD LIBOR to Secured Overnight Financing Rate (SOFR). The Group still has some financial derivatives which are exposed to interest rate benchmarks impacted by IBOR reform:
| - | $400 million of interest rate swaps associated with the $600 million syndicated facility have transitioned to SOFR. A remaining $200 million of interest rate swaps will transition post 30 June 2023 on the swap reset date. |
| - | A cross-currency interest rate swap relating to the fixed-rate 175 million Swiss Franc (CHF) denominated medium term note is due to expire in December 2023. The final interest rate reset in September 2023 will be based on SOFR. |
The transition of the current benchmark rates to alternative benchmark rates did not result in a significant impact to the Group’s financial assets and liabilities.
Fair value
Except for the other financial assets and other financial liabilities set out in this note, there are no other material financial assets or financial liabilities carried at fair value. Other financial assets and other financial liabilities set out in this note are classified as Level 2 on the fair value hierarchy with market observable inputs, with the exception of the embedded commodity derivative which has been classified as Level 3 on the fair value hierarchy with no market observable inputs. Refer to key estimates and judgements for further details. During the period, there were no reclassifications between the fair value hierarchy levels.
With the exception of the embedded commodity derivative, there were no changes to the Group’s valuation processes, valuation techniques and types of inputs used in the fair value measurements during the period.
Financial risk factors
The Group’s activities expose its financial instruments to a variety of market risks, including foreign exchange, commodity price and interest rate risk. The half-year financial report does not include all financial risk management information and disclosures required in the annual report and, as such, should be read in conjunction with the Group’s 2022 Financial Statements. There have been no significant changes in risk management policies since 31 December 2022. Refer to the embedded commodity derivative key estimates and judgements section for the sensitivity assessment on discount rates and pricing.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 39 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
D.3 Other financial assets and liabilities (continued)
Key estimates and judgements
Embedded commodity derivative
The fair value of the Perdaman embedded derivative has been estimated using a Monte Carlo simulation model. The assessment requires management to make certain assumptions about the model inputs, including forecast cash flows, discount rate, credit risk and volatility. These assumptions require significant management judgement and are subject to risk and uncertainty, and hence changes in economic conditions can affect the assumptions. The present value of the embedded derivative was estimated using the assumptions set out below.
| - | Contract term – 20 years; the provision is released as contract deliveries are made up to 2047. |
| - | Contracted gas volumes – 130 terajoules per day of gas. |
| - | Inflation rate – an inflation rate of 2.5% has been applied. |
| - | Discount rate – a pre-tax interest rate curve (range: 6.38% to 8.23%) comprising the SOFR risk-free rate, adjusted for credit risk. |
| - | Domestic gas pricing – forecast sales are subject to urea pricing. Price assumptions are based on the best market information available at measurement date and derived from short- and long-term views of global supply and demand, building upon past experience of the industry and consistent with external sources. The long-term urea price is determined with reference to the prevailing gas hub (Title Transfer Facility (TTF)) prices available in the market at reporting date. |
The embedded derivative is most sensitive to changes in discount rates and pricing, which may result in unrealised gains or losses recognised in other income/expenses. The nominal impact of the effects of changes to discount rate and long-term price assumptions are estimated as follows:
| Change in assumption1 |
US$m | |||
| Urea sales price: increase of 10% |
193 | |||
| Urea sales price: decrease of 10% |
(189 | ) | ||
| Discount rate: increase of 1.5%2 |
(211 | ) | ||
| Discount rate: decrease of 1.5%2 |
264 | |||
| 1. | Amounts shown represent the change of the present value of the contract keeping all other variables constant. |
| 2. | A change of 1.5% represents 150 basis points. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 40 |
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
for the half-year ended 30 June 2023
E. Other items
E.1 Contingent liabilities and assets
| 30 June 2023 US$m |
31 December 2022 US$m |
|||||||
| Contingent liabilities at reporting date |
||||||||
| Not otherwise provided for in the financial statements: |
||||||||
| Contingent liabilities |
70 | 161 | ||||||
| Guarantees |
2 | 2 | ||||||
|
|
|
|
|
|||||
| 72 | 163 | |||||||
|
|
|
|
|
|||||
Contingent liabilities relate predominantly to possible obligations whose existence will only be confirmed by the occurrence or non-occurrence of uncertain future events, and therefore the Group has not provided for such amounts in these condensed half-year financial statements. Additionally, there are a number of other claims and possible claims that have arisen in the course of business against entities in the Group, the outcome of which cannot be estimated at present and for which no amounts have been included in the table above.
The Group has contingent assets of $33 million as at 30 June 2023 (31 December 2022: $199 million).
E.2 Changes to the composition of the Group
There have been no changes to the composition of the Group since the last annual report.
E.3 New standards and interpretations
New and amended accounting standards adopted
A number of amended standards became applicable for the current reporting period. The Group did not make any significant changes to its accounting policies and did not make retrospective adjustments as a result of adopting these amended standards. These amendments did not materially impact the accounting policies or amounts disclosed in the half-year financial statements of the Group.
New standards and interpretations not yet adopted
Certain new accounting standards, amendments to accounting standards and interpretations have been published that are not mandatory for the 30 June 2023 reporting period and have not been early adopted by the Group. These standards, amendments or interpretations are not expected to have a material impact to the Group in the current or future reporting periods and on foreseeable future transactions with the exception of the amendments to AASB 112/ IAS 12 Income Taxes where the impact is under assessment.
Pillar Two reforms
In December 2021, the Organisation for Economic Co-operation and Development (OECD) published its Pillar Two model rules. The Pillar Two model rules:
| - | Aim to ensure that large multinational groups pay a minimum amount of tax on income arising in each jurisdiction in which they operate; and |
| - | Would achieve a minimum effective tax rate in each jurisdiction of 15% from the reporting period commencing 1 January 2024. |
The impact of the Pillar Two reforms is under assessment.
E.4 Events after the end of the reporting period
On 8 August 2023, the Group and LJ Scarborough Pty Ltd (LNG Japan) entered into a Sale and Purchase Agreement for LNG Japan to acquire a 10% non-operating participating interest in the Scarborough Joint Venture (the transaction). The purchase price is $500 million, subject to adjustments. LNG Japan will reimburse the Group for its share of expenditure for the Scarborough project from the effective date of 1 January 2022. On completion of the transaction, expected in the first quarter of 2024, the estimated total consideration comprising the purchase price, reimbursed expenditure and escalation is approximately $880 million. The financial effects of this transaction have not been recognised as at 30 June 2023.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 41 |
DIRECTORS’ DECLARATION
For the half-year ended 30 June 2023
In accordance with a resolution of directors of Woodside Energy Group Ltd, we state that:
In the opinion of the directors:
| a) | the financial statements and notes of the Group are in accordance with the Australian Corporations Act 2001, including: |
| i. | giving a true and fair view of the Group’s financial position as at 30 June 2023 and of its performance for the half-year ended on that date; and |
| ii. | complying with Accounting Standard AASB 134 Interim Financial Reporting and the Corporations Regulations 2001; |
| b) | there are reasonable grounds to believe that Woodside Energy Group Ltd will be able to pay its debts as and when they become due and payable. |
For the purposes of the UK Disclosure Guidance and Transparency Rules, the directors confirm that to the best of their knowledge:
| a) | the financial statements, prepared in accordance with applicable set of accounting standards, give a true and fair view of the assets, liabilities, financial position and profit or loss of Woodside Energy Group Ltd and the undertakings included in the consolidation taken as a whole; and |
| b) | the half-year report includes a fair review of the: |
| i. | important events that have occurred during the first six months of the financial year and their impact on the half-year financial statements; |
| ii. | principal risks and uncertainties for the remaining six months of the financial year; and |
| iii. | related party transactions that have taken place in the first six months of the financial year and that have materially affected financial position or performance during that period and any changes in the related party transactions described in the last annual report that could have a material effect on financial position or performance in the first six months of the financial year. |
On behalf of the Board
|
| |||
| R J Goyder, AO Chair Perth, Western Australia 22 August 2023 |
M E O’Neill Chief Executive Officer and Managing Director Sydney, New South Wales 22 August 2023 | |||
| Woodside Energy Group Ltd | Half-Year Report 2023 | 42 |
INDEPENDENT REVIEW REPORT
Independent auditor’s review report to the members of Woodside Energy Group Ltd
Report on the half-year financial report
Conclusion
We have reviewed the half-year financial report of Woodside Energy Group Ltd (the Company) and the entities it controlled during the half-year (together the Group), which comprises the condensed consolidated statement of financial position as at 30 June 2023, the condensed consolidated income statement, the condensed consolidated statement of comprehensive income, the condensed consolidated statement of cash flows and the condensed consolidated statement of changes in equity for the half-year ended on that date, material accounting policy information and explanatory notes and the directors’ declaration.
Based on our review, which is not an audit, we have not become aware of any matter that makes us believe that the accompanying half-year financial report of Woodside Energy Group Ltd does not comply with the Corporations Act 2001 including:
| 1. | giving a true and fair view of the Group’s financial position as at 30 June 2023 and of its performance for the half-year ended on that date |
| 2. | complying with Accounting Standard AASB 134 Interim Financial Reporting and the Corporations Regulations 2001. |
Basis for conclusion
We conducted our review in accordance with ASRE 2410 Review of a Financial Report Performed by the Independent Auditor of the Entity (ASRE 2410). Our responsibilities are further described in the Auditor’s responsibilities for the review of the half-year financial report section of our report.
We are independent of the Group in accordance with the auditor independence requirements of the Corporations Act 2001 and the ethical requirements of the Accounting Professional & Ethical Standards Board’s APES 110 Code of Ethics for Professional Accountants (including Independence Standards) (the Code) that are relevant to the audit of the annual financial report in Australia. We have also fulfilled our other ethical responsibilities in accordance with the Code.
Responsibilities of the directors for the half-year financial report
The directors of the Company are responsible for the preparation of the half-year financial report that gives a true and fair view in accordance with Australian Accounting Standards and the Corporations Act 2001 and for such internal control as the directors determine is necessary to enable the preparation of the half-year financial report that gives a true and fair view and is free from material misstatement whether due to fraud or error.
PricewaterhouseCoopers, ABN 52 780 433 757
Brookfield Place, 125 St Georges Terrace, PERTH WA 6000, GPO Box D198, PERTH WA 6840
T: +61 8 9238 3000, F: +61 8 9238 3999, www.pwc.com.au
Liability limited by a scheme approved under Professional Standards Legislation.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 43 |
Auditor’s responsibilities for the review of the half-year financial report
Our responsibility is to express a conclusion on the half-year financial report based on our review. ASRE 2410 requires us to conclude whether we have become aware of any matter that makes us believe that the half-year financial report is not in accordance with the Corporations Act 2001 including giving a true and fair view of the Group’s financial position as at 30 June 2023 and of its performance for the half-year ended on that date, and complying with Accounting Standard AASB 134 Interim Financial Reporting and the Corporations Regulations 2001.
A review of a half-year financial report consists of making enquiries, primarily of persons responsible for financial and accounting matters, and applying analytical and other review procedures. A review is substantially less in scope than an audit conducted in accordance with Australian Auditing Standards and consequently does not enable us to obtain assurance that we would become aware of all significant matters that might be identified in an audit. Accordingly, we do not express an audit opinion.
PricewaterhouseCoopers
|
N M Henry |
A G B Hodge | |
| Partner Perth, Western Australia 22 August 2023 |
Partner Perth, Western Australia 22 August 2023 |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 44 |
Appendix 4D
Dividends
| Ex-dividend date | 31 August 2023 | |||||
| Record date for the interim dividend | 1 September 2023 | |||||
| Date the dividend is payable | 28 September 2023 | |||||
| Current period | Previous corresponding period1 | |||||
| Interim dividend – fully franked | US cents per share | 80 | 109 |
None of these dividends are foreign sourced.
Woodside dividends are determined and declared in US dollars. However, shareholders will receive their dividend in Australian dollars unless their registered address is in the United Kingdom (in which case they will receive their dividend in British pounds), in the United States of America (in which case they will receive their dividend in US dollars) or in New Zealand (in which case they will receive their dividend in NZ dollars).
Shareholders who reside outside of the United States can elect to receive their dividend electronically in US dollars, payable into a US financial institution account. Shareholders who reside outside of the United States, the United Kingdom, New Zealand and Australia may elect to receive their dividend electronically in their local currency using Global Wire Payment Service from the Company’s share registry, Computershare Investor Services Pty Ltd.
Shareholders should contact the Company’s share registry if they wish to alter their dividend currency for future dividend payments. Contact details are available on Woodside’s website on the Shareholder Information section of the Investors page. Shareholders must make an election to alter their dividend currency on or before 5.00pm AWST on 5 September 2023.
Currency conversion will be based on the foreign currency exchange rates prevailing on or around the dividend record date of 1 September 2023.
Net Tangible Assets (NTA) per ordinary security
| Current period US$ |
Previous corresponding period1 US$ | |||
| Net Tangible Assets (US$ per ordinary security)2 |
16.40 | 15.06 |
Details of Associates and Joint Venture Entities
| Percentage of ownership interest held at end of period or date of disposal | ||||
| Name of entity |
Current period | Previous corresponding period1 | ||
| North West Shelf Gas Pty Ltd |
33.33% | 33.33% | ||
| North West Shelf Liaison Company Pty Ltd |
33.33% | 33.33% | ||
| China Administration Company Pty Ltd |
33.33% | 33.33% | ||
| International Gas Transportation Company Limited |
33.33% | 33.33% | ||
| North West Shelf Shipping Service Company Pty Ltd |
33.33% | 33.33% | ||
| North West Shelf Lifting Coordinator Pty Ltd |
33.33% | 33.33% | ||
| Blue Ocean Seismic Services Limited |
28.50% | 28.50% | ||
| Iwilei District Participating Parties, LLC |
14.96% | 14.96% | ||
| Caesar Oil Pipeline Company, LLC |
25.00% | 25.00% | ||
| Cleopatra Gas Gathering Company LLC |
22.00% | 22.00% | ||
| Marine Well Containment Company LLC |
10.00% | 10.00% | ||
| 1 | Comparisons are to half-year ended 30 June 2022. |
| 2 | Includes lease assets and liabilities as a result of AASB 16 Leases. Net Tangible Assets is a non-IFRS measure. Refer to Alternative Performance Measures for a reconciliation for these measures to Woodside’s financial statements on pages 51-52. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 45 |
Shareholder information
Key announcements 2023
| January | Fourth quarter 2022 report | |
| February | Line-item guidance and other items | |
| Full-year 2022 results and briefing | ||
| Annual Report 2022 | ||
| Sustainable Development Report 2022 | ||
| Climate Report 2022 | ||
| March | Changes to Woodside Board | |
| April | First quarter 2023 report | |
| Appointment of Executive Vice President Australian Operations | ||
| June | Fatality at North Rankin Complex | |
| Woodside approves investment in Trion development | ||
| Report on payments to governments 2022 | ||
| July | Sangomar project update | |
| Second quarter 2023 report | ||
| August | Woodside to sell 10% Scarborough interest to LNG Japan |
Events calendar 2023-2024
Key calendar dates for Woodside shareholders in 2023-24. Please note dates are subject to review.
| August | 22 | Half-year 2023 results | ||
| 31 | Ex-dividend date for interim dividend | |||
| September | 1 | Record date for interim dividend | ||
| 28 | Payment date for interim dividend | |||
| October | 18 | Third quarter 2023 report | ||
| November | 8 | Investor Briefing Day 2023 | ||
| December | 31 | Year-end 2023 | ||
| January | Fourth quarter 2023 report |
Business directory
| Registered office: |
Postal address: | |
| Woodside Energy Group Ltd Mia Yellagonga 11 Mount Street Perth WA 6000 Australia |
GPO Box D188 Perth WA 6840 Australia
T: +61 8 9348 4000 |
Investor enquiries
Investors seeking information on the company should contact Investor Relations at:
| Postal address: |
||
| Investor Relations GPO Box D188 Perth WA 6840 Australia |
T: +61 8 9348 4000 E: investor@woodside.com W: woodside.com |
Share registry enquiries
Investors seeking information about their shareholdings should contact the company’s share registry:
| Registered office: |
Postal address: | |
| Computershare Investor Services Pty Limited Level 11 172 St Georges Terrace Perth WA 6000 |
GPO Box D182 Perth WA 6840
T: 1300 558 507 (within Australia) +61 3 9415 4632 (outside Australia) E: web.queries@computershare.com.au W: investorcentre.com/wds |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 46 |
The share registry can assist with queries on share transfers, dividend payments, the dividend reinvestment plan, notification of tax file numbers and changes of name, address or bank account details.
Details of shareholdings can be checked by visiting the share registry website at www.investorcentre.com/wds.
Details of our registrar in the United Kingdom and our authorised depositary bank for Woodside’s American Depositary Receipt programme can be found on our website.
Assets
Producing facilities
Australia
| Asset |
Role |
Equity | Product | |||
| Pluto LNG | Operator | 90% | LNG, pipeline gas and condensate | |||
| North West Shelf1 | Operator | 33.33% | LNG, pipeline gas, condensate and NGLs | |||
| Wheatstone | Non-operator | 13% | LNG, pipeline gas and condensate | |||
| Julimar-Brunello | Operator | 65% | ||||
| Okha FPSO | Operator | 50% | Crude oil | |||
| Ngujima-Yin FPSO | Operator | 60% | Crude oil | |||
| Bass Strait | Non-operator | 32.5-50% | Crude oil, pipeline gas, condensate and NGLs | |||
| Pyrenees FPSO | Operator | 40-71.4% | Crude oil | |||
| Macedon | Operator | 71.4% | Pipeline gas |
| 1. | The North West Shelf consists of a number of active joint ventures. Woodside’s participating interest is 33.33% in all of these apart from the NWS joint ventures with CNOOC. Woodside’s participating interest in the CLNG JV is 25% and in the Extended Interest JVs is 31.567%. |
International
| Asset |
Role |
Equity | Product | |||
| Greater Angostura | Operator | 45-68.46% | Crude oil and pipeline gas | |||
| Greater Shenzi | Operator | 72% | Crude oil, pipeline gas, condensate and NGLs | |||
| Atlantis | Non-operator | 44% | Crude oil, pipeline gas, condensate and NGLs | |||
| Mad Dog | Non-operator | 23.9% | Crude oil, pipeline gas, condensate and NGLs |
Projects
Post FID
| Asset |
Role |
Equity | Product | |||
| Scarborough1 | Operator | 100%2 | LNG, pipeline gas and condensate | |||
| Sangomar | Operator | 82% | Crude oil | |||
| Trion | Operator | 60% | Crude oil |
| 1. | “Scarborough” includes the Scarborough field. Woodside is also operator of Pluto Train 2, which achieved FID in 2021, and holds a 51% participating interest. |
| 2. | On completion of the Transaction to sell a 10% interest in the Scarborough Joint Venture to LNG Japan, Woodside will hold a 90% interest and remain as operator. Completion is expected in Q1 2024. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 47 |
Developments
| Asset |
Role |
Equity | Product | |||
| Calypso | Operator | 70% | Gas | |||
| Browse | Operator | 30.6% | LNG, pipeline gas and condensate | |||
| Greater Scarborough1 | Operator | 100% | Gas | |||
| Liard | Operator | 100% | Gas | |||
| Non-operator | 50% | Gas | ||||
| Sunrise | Operator | 33.44% | LNG, pipeline gas and condensate |
| 1. | “Greater Scarborough” includes the Jupiter and Thebe fields. |
New energy opportunities
| Asset |
Role |
Equity | Product | |||
| H2OK | Operator | 100% | Hydrogen | |||
| H2Perth | Operator | 100% | Hydrogen and ammonia | |||
| Hydrogen Refueller@H2Perth | Operator | 100% | Hydrogen | |||
| H2TAS | Operator | 100% | Hydrogen and ammonia | |||
| Woodside Solar | Operator | 100% | Solar energy | |||
| Southern Green Hydrogen1 | Preferred partner | — | Hydrogen and ammonia | |||
| Heliogen2 | Non-operating partner | N/A | Solar energy | |||
| Carbon to Ethanol Pilot Plant3 | Operator | 100% | Carbon capture and utilisation |
| 1. | Woodside’s equity in Southern Green Hydrogen is subject to finalising commercial agreements. |
| 2. | Pilot or demonstration scale facility. Woodside is investing in pilot projects and demonstration scale facilities to assess new energy technologies and build demand for new energy products ahead of their potential deployment on a larger scale. |
Greenhouse gas assessment permits
| Country |
Permit |
Role |
Joint venture |
Comment | ||||
| Australia | G-7-AP | Non-operator | Bonaparte CCS Assessment Joint Venture | Located in the Bonaparte Basin off the north-western coast of the Northern Territory | ||||
| G-8-AP | Operator | Browse Joint Venture | For carbon capture and storage evaluation for Browse | |||||
| G-10-AP | Operator | Northern Carnarvon Basin CCS Joint Venture | Located in the Northern Carnarvon Basin off the north west coast of Western Australia |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 48 |
Exploration
| Country |
Permit |
Role |
Equity |
Product | ||||
| Asia – Pacific |
||||||||
| Australia | WA-356-P | Operator | 65% | Gas prone basin | ||||
| WA-404-P | Operator | 100% | Gas prone basin | |||||
| WA-536-P | Operator | 65% | Gas prone basin | |||||
| WA-550-P | Operator | 100% | Gas prone basin | |||||
| NT/P86 | Operator | 100% | Gas prone basin | |||||
| Europe |
||||||||
| Ireland | FEL 5/13 | Operator | Exit initiated | Oil or gas prone basin | ||||
| Africa |
||||||||
| Senegal | Rufisque, Sangomar and Sangomar Deep | Operator | 90% | Oil prone basin | ||||
| Congo | Marine XX | Non-operator | 22.5% | Oil or gas prone basin | ||||
| Egypt | Red Sea Block 1 | Non-operator | 45% | Oil or gas prone basin | ||||
| Red Sea Block 3 | Non-operator | 30% | Oil and gas prone basin | |||||
| Red Sea Block 4 | Non-operator | 25% | Oil and gas prone basin | |||||
| North Sidi Barrani Offshore (Block 2) | Non-operator | 27% | Oil and gas prone basin | |||||
| North El Dabaa Offshore (Block 4) | Non-operator | 27% | Oil and gas prone basin | |||||
| Caribbean |
||||||||
| Barbados | Carlisle Bay, Bimshire Bay | Operator | 60% | Oil or gas prone basin | ||||
| Latin America |
||||||||
| Peru | 108 | Non-operator | Exit initiated | Oil or gas prone basin | ||||
| North America |
||||||||
| US Gulf of Mexico | GB 640, GB 641, GB 685, GB 555, GB 726, GB 770, GB 771, GB 604, GB 605, GB 647, GB 648, GB 772, GB 728, GB 729, GB 773, GB 774, GB 421, GB 464, GB 465, GB 508, GB 509, GC 598 | Non-operator | 40% | Oil prone basin | ||||
| GB 574, GB 575, GB 619, GB 529, GB 530, GB 531 | Operator | 40% | Oil prone basin | |||||
| GC 436, GC 480 | Non-operator | 44% | Oil prone basin | |||||
| GB 501, GB 502, GB 545, GB 630, GB 672, GB 676, GB 677, GB 716, GB 719, GB 720, GB 721, GB 760, GB 762, GB 763, GB 805, GB 806, GB 807, GB 851, GB 852, GB 895 | Operator | 60% | Oil prone basin | |||||
| GC 282, GC 237 | Non-operator | 50% | Oil prone basin | |||||
| GB 663, GB 664, GB 678, GC 564, GC 210, GC 211, AC 125, AC 126 | Operator | 100% | Oil prone basin | |||||
| EB 655, EB 656, EB 699, EB 700, EB 701, EB 566, EB 567, EB 610, EB 611, AC 34, AC 36, | Operator | 70% | Oil prone basin |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 49 |
| Country |
Permit |
Role |
Equity |
Product | ||||
| AC 78, AC 80, EB 870, EB 871, EB 872, EB 914, EB 915, EB 742, EB 785, EB 786, EB 830, AC 127, AC 170, AC 39, AC 81, AC 82 | ||||||||
| MC 798, MC 842 | Non-operator | 45% | Oil prone basin | |||||
| GC 679, GC 768 | Non-operator | 31.9% | Oil prone basin | |||||
| GC 238 | Non-operator | 60% | Oil prone basin | |||||
| MC 368, MC 369, MC 411, MC 412, MC 455, MC 456 | Non-operator | 25% | Oil prone basin | |||||
| GC 80, GC 123, GC 124, GC 168 | Operator | 75% | Oil prone basin | |||||
| GC 738, GC 870 | Non-operator | 23.9% | Oil prone basin |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 50 |
Alternative Performance Measures
Woodside uses various alternative performance measures (APM) which are non-IFRS measures that are unaudited but derived from our Half-Year Financial Statements. These measures are presented to provide further insight into Woodside’s performance. See Non-IFRS Measures on page 56 for more information.
APMs and their nearest respective IFRS measure.
| APMs derived from the condensed consolidated half-year financial statements and its accompanying notes |
30 June 2023 US$m |
30 June 2022 US$m |
||||||
| EBIT/EBITDA excluding impairment |
||||||||
| Net profit after tax |
1,766 | 1,679 | ||||||
| Adjusted for: |
||||||||
| Finance income |
(174 | ) | (31 | ) | ||||
| Finance costs |
137 | 86 | ||||||
| PRRT expense |
778 | 424 | ||||||
| Income tax expense |
284 | 824 | ||||||
|
|
|
|
|
|||||
| EBIT |
2,791 | 2,982 | ||||||
|
|
|
|
|
|||||
| Adjusted for: |
||||||||
| Oil and gas properties depreciation and amortisation |
1,944 | 924 | ||||||
| Amortisation of licence acquisition costs |
4 | 3 | ||||||
| Depreciation of lease assets |
81 | 62 | ||||||
| Impairment losses |
68 | — | ||||||
|
|
|
|
|
|||||
| EBITDA excluding impairment |
4,888 | 3,971 | ||||||
|
|
|
|
|
|||||
| Underlying NPAT |
||||||||
| Net profit after tax attributable to equity holders of the parent |
1,740 | 1,640 | ||||||
| Adjusted for the following exceptional items: |
||||||||
| Add: Derecognition of Pluto PRRT (post-tax) |
446 | — | ||||||
| Add: Impairment losses (post-tax) |
29 | — | ||||||
| Add: Merger transaction costs |
— | 424 | ||||||
| Less: Trion DTA recognition |
(319 | ) | — | |||||
| Less: Derecognition of the Corpus Christi onerous contract provision |
— | (245 | ) | |||||
|
|
|
|
|
|||||
| Underlying NPAT |
1,896 | 1,819 | ||||||
|
|
|
|
|
|||||
| Capital expenditure |
||||||||
| Capital additions on evaluation |
76 | — | ||||||
| Capital additions on oil and gas properties |
2,555 | 1,509 | ||||||
|
|
|
|
|
|||||
| Capital expenditure |
2,631 | 1,509 | ||||||
|
|
|
|
|
|||||
| Exploration expenditure |
||||||||
| Exploration and evaluation expenditure |
138 | 44 | ||||||
| Adjusted for: |
||||||||
| Amortisation expense |
(4 | ) | (3 | ) | ||||
| Prior year expense written off |
(1 | ) | — | |||||
| Exploration capitalised |
54 | — | ||||||
|
|
|
|
|
|||||
| Exploration expenditure |
187 | 41 | ||||||
|
|
|
|
|
|||||
| Investment expenditure |
2,818 | 1,550 | ||||||
|
|
|
|
|
|||||
| Free cash flow |
||||||||
| Cash flow from operating activities1 |
2,931 | 2,506 | ||||||
| Cash flow (used in)/from investing activities |
(2,637 | ) | 45 | |||||
|
|
|
|
|
|||||
| Free cash flow |
294 | 2,551 | ||||||
|
|
|
|
|
|||||
| 1. | H1 2022 comparative has been restated due to the reclassification of purchases of shares and payments relating to employee share plans from cash flows from financing activities to cash flows from operating activities. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 51 |
| APMs derived from the condensed consolidated half-year financial statements and its accompanying notes |
30 June 2023 US$m |
30 June 2022 US$m |
||||||
| Net tangible assets per ordinary security |
||||||||
| Net assets |
36,684 | 33,424 | ||||||
| Adjusted for: |
||||||||
| Goodwill |
(4,669 | ) | (3,975 | ) | ||||
| Non-controlling interest |
(775 | ) | (790 | ) | ||||
| Intangible assets |
(103 | ) | (64 | ) | ||||
|
|
|
|
|
|||||
| Net tangible assets |
31,137 | 28,595 | ||||||
|
|
|
|
|
|||||
| Number of issued and fully paid shares |
1,898,749,771 | 1,898,749,771 | ||||||
|
|
|
|
|
|||||
| Net tangible assets per ordinary security |
16.40 | 15.06 | ||||||
|
|
|
|
|
|||||
| Gearing |
||||||||
| Interest-bearing liabilities (Current and non-current) |
5,109 | 5,380 | ||||||
| Lease liabilities (Current and non-current) |
1,570 | 1,618 | ||||||
| Adjusted for: |
||||||||
| Cash and cash equivalents |
(3,469 | ) | (4,615 | ) | ||||
| Add: Restricted cash |
10 | — | ||||||
|
|
|
|
|
|||||
| Net debt |
3,220 | 2,383 | ||||||
|
|
|
|
|
|||||
| Equity attributable to equity holders of the parent |
35,909 | 32,634 | ||||||
|
|
|
|
|
|||||
| Total net debt and equity attributable to equity holders of the parent |
39,129 | 35,017 | ||||||
|
|
|
|
|
|||||
| Gearing (%) |
8.2 | 6.8 | ||||||
|
|
|
|
|
|||||
| Woodside Energy Group Ltd | Half-Year Report 2023 | 52 |
Notes
Glossary
| Term |
Definition | |
| $, $m | US dollars unless otherwise stated, millions of dollars | |
| 1P | Proved reserves | |
| 2C | Best Estimate of Contingent resources | |
| 2P | Proved plus Probable reserves | |
| ASX | Australian Securities Exchange | |
| A$, AUD | Australian dollars | |
| BHP Petroleum or BHPP | Woodside Energy Global Holdings Pty Ltd ACN 006 923 897 (formerly known as BHP Petroleum International Pty Ltd) and, unless context otherwise requires, its subsidiaries. References to “Woodside Energy Global Holdings Pty Ltd” or “BHP Petroleum International Pty Ltd” are references to Woodside Energy Global Holdings Pty Ltd ACN 006 923 897 (formerly known as BHP Petroleum International Pty Ltd) excluding its subsidiaries. | |
| Brent | Intercontinental Exchange (ICE) Brent Crude deliverable futures contract (oil price) | |
| Capital expenditure | Includes capital additions on oil and gas properties and evaluation capitalised | |
| Carbon credit | A tradeable financial instrument that is issued by a carbon-crediting program. A carbon credit represents a greenhouse gas emission reduction to, or removal from, the atmosphere equivalent to 1 tCO2-e, calculated as the difference in emissions from a baseline scenario to a project scenario. Carbon credits are uniquely serialised, issued, tracked and retired or administratively cancelled by means of an electronic registry operated by an administrative body, such as a carbon-crediting program | |
| Cash margin | Revenue from sale of produced hydrocarbons less production costs, royalties, excise and levies, insurance, inventory movement, shipping and direct sales costs and other hydrocarbon costs; excludes exploration and evaluation, general administrative and other costs, depreciation and amortisation, PRRT and income tax | |
| CCS | Carbon capture and storage | |
| CCUS | Carbon capture utilisation and storage | |
| CHF | Swiss francs | |
| CO2 | Carbon dioxide | |
| CO2-e | CO2 equivalent. The universal unit of measurement to indicate the global warming potential of each of the seven greenhouse gases, expressed in terms of the global warming potential of one unit of carbon dioxide. It is used to evaluate releasing (or avoiding releasing) any greenhouse gas against a common basis1 | |
| Condensate | Hydrocarbons that are gaseous in a reservoir but that condense to form liquids as they rise to the surface | |
| cps | Cents per share | |
| Decarbonisation | Woodside uses this term to describe activities or pathways that have the effect of moving towards a state that is lower carbon, as defined in this glossary | |
| DRP | Dividend reinvestment plan | |
| EBIT | Calculated as profit before income tax, PRRT and net finance costs | |
| EBITDA excluding impairment | Calculated as profit before income tax, PRRT, net finance costs, depreciation and amortisation, impairment losses, impairment reversals | |
| EPS | Earnings per share | |
| Exploration expenditure | Includes exploration and evaluation expenditure less amortisation of licence acquisition costs and prior year exploration expense written off | |
| FEED | Front-end engineering design | |
| FID | Final investment decision | |
| FPSO | Floating production storage and offloading | |
| FPU | Floating production unit | |
| Free cash flow | Cash flow from operating activities and cash flow from investing activities | |
| GAAP | Generally Accepted Accounting Principles | |
| Gearing | Net debt divided by the total of net debt and equity attributable to equity holders of the parent. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 53 |
| GHG or greenhouse gas | The seven greenhouse gases listed in the Kyoto Protocol are: carbon dioxide (CO2); methane (CH4); nitrous oxide (N2O); hydrofluorocarbons (HFCs); nitrogen trifluoride (NF3); perfluorocarbons (PFCs); and sulphur hexafluoride (SF6)1 | |
| Gross margin | Gross profit divided by operating revenue. Gross profit excludes income tax, PRRT, net finance costs, other income and other expenses | |
| GWF | Greater Western Flank | |
| H1 | H1 is 1 January to 30 June | |
| HSE | Health, safety and environment | |
| IFRS | International Financial Reporting Standards | |
| Investment expenditure | Includes capital expenditure and exploration expenditure | |
| JV | Joint venture | |
| KGP | Karratha Gas Plant | |
| Liquidity | Total cash and cash equivalents and available undrawn debt facilities less restricted cash | |
| LNG | Liquified natural gas | |
| Lower carbon | Woodside uses this term to describe the characteristic of having lower levels of associated potential GHG emissions when compared to historical and/or current conventions or analogues, for example relating to an otherwise similar resource, process, production facility, product or service, or activity | |
| Lower carbon services | Woodside uses this term to describe technologies, such as CCUS or offsets that could be used by customers to reduce their net greenhouse gas emissions | |
| LSE | London Stock Exchange | |
| Net debt | Interest-bearing liabilities and lease liabilities less cash and cash equivalents | |
| Net profit attributable to equity holders of the parent | Net profit after tax excluding non-controlling interests from the Group’s operations | |
| Net tangible assets | The Group’s net assets less goodwill, non-controlling interest and intangible assets | |
| Net tangible assets per ordinary security | Net tangible assets divided by the number of issued and fully paid shares | |
| New energy | Woodside uses this term to describe energy technologies, such as hydrogen or ammonia, that are emerging in scale but which are expected to grow during the energy transition due to having lower greenhouse gas emissions at the point of use than conventional fossil fuels | |
| NGLs | Natural gas liquids | |
| NPAT | Net profit after tax attributable to equity holders of the parent | |
| NWS | North West Shelf | |
| NYSE | New York Stock Exchange | |
| Offsets | The compensation for an entity’s greenhouse gas emissions within its scope by achieving an equivalent amount of emission reductions or removals outside the boundary or value chain of that entity | |
| PRRT | Petroleum resources rent tax | |
| PSC | Production sharing contract | |
| Revenue from ordinary activities | Revenue from the sale of hydrocarbons, processing and services revenue and shipping and other revenue. | |
| RFSU | Ready for start-up | |
| Significant environmental event | Unplanned or undesired event resulting in a moderate, medium-term impact on ecosystem, species, habitat or physical or biological attributes. | |
| Target | Woodside uses this term to describe an intention to seek the achievement of an outcome, where Woodside considers that it has developed a suitably defined plan or pathway to achieve that outcome | |
| TCFD | Taskforce on Climate-related Financial Disclosures | |
| TRIR | Total recordable injury rate. The number of recordable injuries (fatalities, lost workday cases, restricted work day cases and medical treatment cases) per million work hours | |
| Underlying NPAT | Net profit after tax from the Group’s operations excluding any exceptional items | |
| Unit production costs | Production costs ($ million) divided by production volume (MMboe) | |
| US, USA | United States of America | |
| USD | US dollars | |
| WA | Western Australia |
| 1 | See IFRS Foundation 2021: Climate Related Disclosures Prototype. Appendix A. The IFRS published a further consultation document subsequent to the 2021 prototype. As it did not contain an updated definition of Paris-Aligned scenarios Woodside has retained use of the previous edition. |
| Woodside Energy Group Ltd | Half-Year Report 2023 | 54 |
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 (NGLs) | 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
Units of measure
| Term | Definition | |||
| bbl | barrel | |||
| Bcf | billion cubic feet of gas | |||
| boe | barrel of oil equivalent | |||
| CO2-e | carbon dioxide equivalent | |||
| ha | hectare | |||
| Mbbl | thousand barrels | |||
| Mboe | thousand barrels of oil equivalent | |||
| MMboe | million barrels of oil equivalent | |||
| MMBtu | million British thermal units | |||
| MMscf | million standard cubic feet of gas | |||
| mtpa | million tonnes per annum | |||
| MW | megawatt | |||
| Scf | standard cubic feet of gas | |||
| tpd | tonnes per day | |||
About this report
This Half-Year Report 2023 is a summary of Woodside’s operations, activities and financial position as at 30 June 2023. Woodside Energy Group Ltd (ABN 55 004 898 962) is the parent company of the Woodside group of companies. In this report, unless otherwise stated, references to ‘Woodside’, ‘the company’, ‘the Group’, ‘we’, ‘us’ and ‘our’ refer to Woodside Energy Group Ltd and its controlled entities as a whole. The text does not distinguish between the activities of the parent company and those of its controlled entities.
References to ‘H1’ refer to the first half of the year, i.e. the period between 1 January 2023 and 30 June 2023. All dollar figures are expressed in US currency unless otherwise stated. Production and sales volumes, reserves and resources are quoted as Woodside share. A glossary of key terms, units of measure and conversion factors is on pages 53-55.
This report should be read in conjunction with the Annual Report 2022, Sustainable Development Report 2022 and the Climate Report 2022, available on Woodside’s website, www.woodside.com.
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 development, completion and execution of Woodside’s projects, expectations regarding future capital expenditures, future results of projects, operating activities, new energy products, expectations and plans for renewables production capacity and investments in, and development of, renewables projects and expectations regarding the achievement of Woodside’s net equity Scope 1 and 2 greenhouse gas emissions targets. All statements, other than statements of historical or present facts, are forward-looking statements and generally may be identified by the use of forward-looking words such as ‘guidance’, ‘foresee’, ‘likely’, ‘potential’, ‘anticipate’, ‘believe’, ‘aim’, ‘estimate’, ‘expect’, ‘intend’, ‘may’, ‘target’, ‘plan’, ‘strategy’, ‘forecast’, ‘outlook’, ‘project’, ‘schedule’, ‘will’, ‘should’, ‘seek’ and other similar words or expressions. Similarly, statements that describe the objectives, plans, goals or expectations of Woodside are forward-looking statements.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 55 |
Forward-looking statements in this report are not guidance, forecasts, guarantees or predictions of future events or performance, but are in the nature of future expectations that are based on management’s current expectations and assumptions. Those statements and any assumptions on which they are based are subject to change without notice and are subject to inherent known and unknown risks, uncertainties, assumptions and other factors, many of which are beyond the control of Woodside, its related bodies corporate and their respective officers, directors, employees, advisers or representatives. Important factors that could cause actual results to differ materially from those in the forward-looking statements include, but are not limited to, fluctuations in commodity prices, actual demand, currency fluctuations, geotechnical factors, drilling and production results, gas commercialisation, development progress, operating results, engineering estimates, reserve and resource estimates, loss of market, industry competition, environmental risks, climate related risks, physical risks, legislative, fiscal and regulatory developments, changes in accounting standards, economic and financial markets conditions in various countries and regions, political risks, project delay or advancement, regulatory approvals, the impact of armed conflict and political instability (such as the ongoing conflict in Ukraine) on economic activity and oil and gas supply and demand, cost estimates, the effect of future regulatory or legislative actions on Woodside or the industries in which it operates, including potential changes to tax laws, and the impact of general economic conditions, inflationary conditions, prevailing exchange rates and interest rates and conditions in financial markets.
In addition to the summary of ‘Principal risks and uncertainties’ on page 16 of this report, 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.
All forward-looking statements contained in this report reflect Woodside’s views held as at the date of this report and, except as required by applicable law, Woodside does not intend to, undertake to, or assume any obligation to, provide any additional information or update or revise any of these statements after the date of this report, either to make them conform to actual results or as a result of new information, future events, changes in Woodside’s expectations or otherwise.
Investors are strongly cautioned not to place undue reliance on any forward-looking statements. Actual results or performance may vary materially from those expressed in, or implied by, any forward-looking statements. None of Woodside nor any 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.
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.
Non-IFRS Measures
Throughout this report, a range of financial and non-financial measures are used to assess Woodside’s performance, including a number of financial measures that are not defined in, and have not been prepared in accordance with, International Financial Reporting Standards (IFRS) and are not recognised measures of financial performance or liquidity under IFRS (Non-IFRS Financial Measures). These measures include EBIT, EBITDA excluding impairment, Gearing, Underlying NPAT, Net debt, Free cash flow, Capital expenditure, Exploration expenditure, Investment expenditure, Net tangible assets, and Net tangible asset per ordinary security. These Non-IFRS Financial Measures are defined in the glossary on pages 53-55 of this report. A quantitative reconciliation of these measures to the most directly comparable financial measure calculated and presented in accordance with IFRS can be found in the Alternative Performance Measures section of this report on pages 51-52.
Woodside’s management uses these measures to monitor Woodside’s financial performance alongside IFRS measures to improve the comparability of information between reporting periods and business units and Woodside believes that the Non-IFRS Financial Measures it presents provide a useful means through which to examine the underlying performance of its business.
Undue reliance should not be placed on the Non-IFRS Financial Measures contained in this report and these Non-IFRS Financial Measures should be considered in addition to, and not as a substitute for, or as superior to, measures of financial performance, financial position or cash flows reported in accordance with IFRS. Non-IFRS Financial Measures are not uniformly defined by all companies, including those in Woodside’s industry. Accordingly, they may not be comparable with similarly titled measures and disclosures by other companies.
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Climate strategy and emissions data
All greenhouse gas emissions data in this report are estimates, due to the inherent uncertainty and limitations in measuring or quantifying greenhouse gas emissions, and our methodologies for measuring or quantifying greenhouse gas emissions may evolve as best practices continue to develop and data quality and quantity continue to improve.
Woodside “greenhouse gas” or “emissions” information reported are net equity Scope 1 greenhouse emissions, Scope 2 greenhouse emissions, and/or Scope 3 greenhouse emissions, unless otherwise stated.
For more information on Woodside’s climate strategy and emissions data refer to Woodside’s Climate Report 2022 available on the Woodside website at https://www.woodside.com/sustainability/climate-change.
No express or implied prices
This report does not include any express or implied prices at which Woodside will buy or sell financial products.
| Contacts: |
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| INVESTORS
Matthew Turnbull (Group) M: +61 410 471 079
Sarah Peyman (Australia) M: +61 457 513 249
Rohan Goudge (US) M: +1 (713) 679-1550
E: investor@woodside.com |
MEDIA
Christine Forster M: +61 484 112 469 E: christine.forster@woodside.com |
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This announcement was approved and authorised for release by Woodside’s Disclosure Committee.
| Woodside Energy Group Ltd | Half-Year Report 2023 | 57 |
Exhibit 99.2
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
Tuesday, 22 August 2023
HALF-YEAR 2023 RESULTS TELECONFERENCE AND PRESENTATION
A teleconference providing an overview of the half-year 2023 results and a question-and-answer session will be hosted by Woodside CEO and Managing Director, Meg O’Neill, and Chief Financial Officer, Graham Tiver, today at 08:00 AWST / 10:00 AEST (19:00 CDT on Monday, 21 August 2023).
We recommend participants pre-register 5 to 10 minutes prior to the event with one of the following links:
| • |
https://webcast.openbriefing .com/wds-hyr-2023/ to view the presentation and listen to a live stream of the question-and-answer session |
| • |
https://s1.c-conf. com/diamondpass/10031114-ldyp34.html to participate in the question-and-answer session. Following pre-registration, participants will receive the teleconference details and a unique access passcode. |
The half-year results briefing pack follows this announcement and will be referred to during the teleconference. The briefing pack, Half-Year Report 2023 and teleconference archive will also be available on the Woodside website (www.woodside.com).
| Contacts: | ||||
| INVESTORS | MEDIA | |||
| Matthew Turnbull (Group) | Christine Forster | |||
| M: +61 410 471 079 | M: +61 484 112 469 | |||
| E: christine.forster@woodside.com | ||||
| Sarah Peyman (Australia) | ||||
| M: +61 457 513 249 | ||||
| Rohan Goudge (US) | ||||
| M: +1 (713) 679-1550 | ||||
| E: investor@woodside.com | ||||
This announcement was approved and authorised for release by Woodside’s Disclosure Committee.
HALF-YEAR RESULTS BRIEFING 2023 22 August 2023 www.woodside.com investor@woodside.com
Disclaimer, important notes and assumptions Information historical or present facts, are forward-looking statements and generally may be identified by the use of forward-looking words such as ‘guidance’, ‘foresee’, ‘likely’, ‘potential’, ‘anticipate’, ‘believe’, ‘aim’, ‘estimate’, ‘expect’, ‘intend’, ‘may’, • This presentation has been prepared by Woodside Energy Group Ltd (“Woodside”). ‘target’, ‘plan’, ‘strategy’, ‘forecast’, ‘outlook’, ‘project’, ‘schedule’, ‘will’, ‘should’, ‘seek’ and other similar words or • All information included in this presentation, including any forward-looking statements, reflects Woodside’s views held as expressions. Similarly, statements that describe the objectives, plans, goals or expectations of Woodside are forward- at the date of this presentation and, except as required by applicable law, neither Woodside, its related bodies corporate, looking statements. nor any of their respective officers, directors, employees, advisers or representatives (“Beneficiaries”) intends to, or • Forward-looking statements in this presentation are not guidance, forecasts, guarantees or predictions of future events or undertakes to, or assumes any obligation to, provide any additional information or update or revise any information or performance, but are in the nature of future expectations that are based on management’s current expectations and forward-looking statements in this presentation after the date of this presentation, either to make them conform to actual assumptions. Those statements and any assumptions on which they are based are subject to change without notice and results or as a result of new information, future events, changes in Woodside’s expectations or otherwise. are subject to inherent known and unknown risks, uncertainties, assumptions and other factors, many of which are • This presentation may contain industry, market and competitive position data that is based on industry publications and beyond the control of Woodside, its related bodies corporate and their respective Beneficiaries. Important factors that studies conducted by third parties as well as Woodside’s internal estimates and research. While Woodside believes that could cause actual results to differ materially from those in the forward-looking statements include, but are not limited each of these publications and third party studies is reliable and has been prepared by a reputable source, Woodside has to, fluctuations in commodity prices, actual demand, currency fluctuations, geotechnical factors, drilling and production not independently verified the market and industry data obtained from these third party sources and cannot guarantee results, gas commercialisation, development progress, operating results, engineering estimates, reserve and resource the accuracy or completeness of such data. Accordingly, undue reliance should not be placed on any of the industry, estimates, loss of market, industry competition, environmental risks, climate related risks, physical risks, legislative, fiscal market and competitive position data contained in this presentation. and regulatory developments, changes in accounting standards, economic and financial markets conditions in various • To the maximum extent permitted by law, neither Woodside, its related bodies corporate, nor any of their respective countries and regions, political risks, project delay or advancement, regulatory approvals, the impact of armed conflict Beneficiaries, assume any liability (including liability for equitable, statutory or other damages) in connection with, any and political instability (such as the ongoing conflict in Ukraine) on economic activity and oil and gas supply and responsibility for, or make any representation or warranty (express or implied) as to, the fairness, currency, accuracy, demand, cost estimates, and the effect of future regulatory or legislative actions on Woodside or the industries in which it adequacy, reliability or completeness of the information or any opinions expressed in this presentation or the operates, including potential changes to tax laws, and the impact of general economic conditions, inflationary conditions, reasonableness of any underlying assumptions. prevailing exchange rates and interest rates and conditions in financial markets. No offer or advice • 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 • This presentation is not intended to and does not constitute, form part of, or contain an offer or invitation to sell to and in Woodside’s most recent Annual Report on Form 20-F filed with the United States Securities and Exchange Woodside shareholders (or any other person), or a solicitation of an offer from Woodside shareholders (or any other Commission and available on the Woodside website at https://www.woodside.com/investors/reports-investor-briefings. person), or a solicitation of any vote or approval from Woodside shareholders (or any other person) in any jurisdiction. You should review and have regard to these risks when considering the information contained in this presentation. • This presentation has been prepared without reference to the investment objectives, financial and taxation situation or • Investors are strongly cautioned not to place undue reliance on any forward-looking statements. Actual results or particular needs of any Woodside shareholder or any other person. The information contained in this presentation does performance may vary materially from those expressed in, or implied by, any forward-looking statements. not constitute, and should not be taken as, financial product or investment advice. Woodside encourages you to seek independent legal, financial, taxation and other professional advice before making any investment decision. Notes to petroleum resource estimates • This presentation shall not be distributed, transmitted, published, reproduced or otherwise made available to any other • Unless otherwise stated, all petroleum resource estimates are quoted as at the effective date (i.e. 31 December 2022) of person, in whole or in part, directly or indirectly, for any purposes whatsoever. In particular, this presentation and the the Reserves and Resources Statement included in Woodside’s most recent Annual Report released to the Australian information contained herein may not be taken or transmitted, in, into or from and may not be copied, forwarded, Securities Exchange and the London Stock Exchange and in Woodside’s most recent Annual Report on Form 20-F filed distributed or transmitted in or into any jurisdiction in which such release, publication or distribution would be unlawful. with the United States Securities and Exchange Commission (SEC) and available on the Woodside website at The release, presentation, publication or distribution of this presentation, in whole or in part, in certain jurisdictions may https://www.woodside.com/investors/reports-investor-briefings, net Woodside share at standard oilfield conditions of be restricted by law or regulation, and persons into whose possession this presentation comes should inform themselves 14.696 psi (101.325 kPa) and 60 degrees Fahrenheit (15.56 degrees Celsius). about, and observe, any such restrictions. Any failure to comply with these restrictions may constitute a violation of the • Woodside estimates and reports its Proved (1P) Reserves in accordance with the SEC regulations, which are also laws of the relevant jurisdiction. Woodside does not accept liability to any person in relation to the distribution or compliant with SPE-PRMS guidelines. SEC-compliant Proved (1P) Reserves estimates use a more restrictive, rules-based possession of this document in or from any such jurisdiction. approach and are generally lower than estimates prepared solely in accordance with SPE-PRMS guidelines due to, among Forward-looking statements other things, the requirement to use commodity prices based on the average price during the 12-month period in the reporting company’s fiscal year. Woodside estimates and reports its Proved plus Probable (2P) Reserves and Best Estimate • This presentation contains forward-looking statements with respect to Woodside’s business and operations, market (2C) Contingent Resources in accordance with SPE-PRMS guidelines. conditions, results of operations and financial condition, including, for example, but not limited to, statements regarding development, completion and execution of Woodside’s projects, expectations regarding future capital expenditures, • Woodside is not aware of any new information or data that materially affects the information included in the Reserves future results of projects, operating activities, new energy products, expectations and plans for renewables production and Resources Update. All the material assumptions and technical parameters underpinning the estimates in the Reserves capacity and investments in, and development of, renewables projects, expectations and guidance with respect to and Resources Update continue to apply and have not materially changed. production, investment expenditure and gas hub exposure for 2023, and expectations regarding the achievement of Woodside’s net equity Scope 1 and 2 greenhouse gas emissions targets]. All statements, other than statements of 2
Disclaimer, important notes and assumptions (continued) Notes to petroleum resource estimates (continued) These growth opportunities are subject to relevant joint venture participant approvals, commercial arrangements with third parties and regulatory approvals being obtained in the timeframe contemplated or at all. Woodside expresses no • Woodside reports its petroleum resource estimates inclusive of all fuel consumed in operations. view as to whether its joint venture participants will agree with and support Woodside’s current position in relation to • For offshore oil projects, the reference point is defined as the outlet of the floating production storage and offloading these opportunities, or such commercial arrangements and regulatory approvals will be obtained. Additional assumptions facility (FPSO) or platform, while for the onshore gas projects the reference point is defined as the outlet of the relevant to particular targets or other statements in this presentation may be set out in the relevant slides. Any such downstream (onshore) gas processing facility. additional assumptions are in addition to the assumptions and qualifications applicable to the presentation as a whole. • Woodside uses both deterministic and probabilistic methods for the estimation of Reserves and Contingent Resources at Climate strategy and emissions data the field and project levels. All Proved (1P) Reserves estimates have been estimated using deterministic methodology and • All greenhouse gas emissions data in this presentation are estimates, due to the inherent uncertainty and limitations in reported on a net interest basis in accordance with the SEC regulations and have been determined in accordance with measuring or quantifying greenhouse gas emissions, and our methodologies for measuring or quantifying greenhouse SEC Rule 4-10(a) of Regulation S-X. Unless otherwise stated, all petroleum estimates reported at the company or region gas emissions may evolve as best practices continue to develop and data quality and quantity continue to improve. level are aggregated by arithmetic summation by category. The aggregated Proved (1P) Reserves may be a conservative estimate due to the portfolio effects of arithmetic summation. • Woodside “greenhouse gas” or “emissions” information reported are net equity Scope 1 greenhouse emissions, Scope 2 6 greenhouse emissions, and/or Scope 3 greenhouse emissions, unless otherwise stated. • ‘MMboe’ means millions (10 ) of barrels of oil equivalent. Natural gas volumes are converted to oil equivalent volumes via a constant conversion factor, which for Woodside is 5.7 Bcf of dry gas per 1 MMboe. Volumes of natural gas liquids, • For more information on Woodside’s climate strategy, including references to “lower carbon” as part of that strategy, and oil and condensate are converted from MMbbl to MMboe on a 1:1 ratio. emissions data refer to Woodside’s Climate Report 2022 available on the Woodside website at https://www.woodside.com/sustainability/climate-change. The glossary and footnotes to this presentation provide further Disclosure of reserve information and cautionary note to US investors clarification of “lower carbon” where applicable. • Woodside is an Australian company listed on the Australian Securities Exchange, the New York Stock Exchange and the Non-IFRS Financial Measures London Stock Exchange. As noted above, Woodside estimates and reports its Proved (1P) Reserves in accordance with the SEC regulations, which are also compliant with SPE-PRMS guidelines, and estimates and reports its Proved plus Probable • Throughout this presentation, a range of financial and non-financial measures are used to assess Woodside’s (2P) Reserves and Best Estimate (2C) Contingent Resources in accordance with SPE-PRMS guidelines. Woodside reports all performance, including a number of financial measures that are not defined in, and have not been prepared in of its petroleum resource estimates using definitions consistent with the 2018 Society of Petroleum Engineers (SPE)/World accordance with, International Financial Reporting Standards (IFRS) and are not recognised measures of financial Petroleum Council (WPC)/American Association of Petroleum Geologists (AAPG)/Society of Petroleum Evaluation performance or liquidity under IFRS (Non-IFRS Financial Measures). These measures include EBIT, EBITDA, EBITDA Engineers (SPEE) Petroleum Resources Management System (PRMS). excluding impairment, Gearing, Underlying NPAT, Net debt, Free cash flow, Cash margin, Capital expenditure, Exploration expenditure. These Non-IFRS Financial Measures are defined in the glossary section of this presentation. A quantitative • The SEC permits oil and gas companies, in their filings with the SEC, to disclose only Proved, Probable and Possible reconciliation of these measures to the most directly comparable financial measure calculated and presented in Reserves, and only when such Reserves have been determined in accordance with the SEC guidelines. In this presentation, accordance with IFRS can be found in Woodside’s Half Year Report for the period ended 30 June 2023. Woodside includes estimates of quantities of oil and gas using certain terms, such as “Proved plus Probable (2P) Reserves”, “Best Estimate (2C) Contingent Resources”, “Reserves and Contingent Resources”, “Proved plus Probable”, • Woodside’s management uses these measures to monitor Woodside’s financial performance alongside IFRS measures to “Developed and Undeveloped”, “Probable Developed”, “Probable Undeveloped”, “Contingent Resources” or other improve the comparability of information between reporting periods and business units and Woodside believes that the descriptions of volumes of reserves, which terms include quantities of oil and gas that may not meet the SEC’s definitions Non-IFRS Financial Measures it presents provide a useful means through which to examine the underlying performance of of proved, probable and possible reserves, and which the SEC’s guidelines strictly prohibit Woodside from including in its business. filings with the SEC. These types of estimates do not represent, and are not intended to represent, any category of • Undue reliance should not be placed on the Non-IFRS Financial Measures contained in this presentation and these Non- reserves based on SEC definitions, and may differ from and may not be comparable to the same or similarly-named IFRS Financial Measures should be considered in addition to, and not as a substitute for, or as superior to, measures of measures used by other companies. These estimates are by their nature more speculative than estimates of proved financial performance, financial position or cash flows reported in accordance with IFRS. Non-IFRS Financial Measures are reserves, and accordingly are subject to substantially greater risk of being recovered by Woodside. In addition, actual not uniformly defined by all companies, including those in Woodside’s industry. Accordingly, they may not be locations drilled and quantities that may be ultimately recovered from Woodside’s properties may differ substantially. US comparable with similarly titled measures and disclosures by other companies. investors are urged to consider closely the disclosures in Woodside’s most recent Annual Report on Form 20-F filed with Other important information the SEC and available on the Woodside website at https://www.woodside.com/investors/reports-investor-briefings and its • All references to dollars, cents or $ in this presentation are to US currency, unless otherwise stated. other filings with the SEC, which are available from Woodside at https://www.woodside.com. These reports can also be obtained from the SEC at www.sec.gov. • References to “Woodside” may be references to Woodside Energy Group Ltd and/or its applicable subsidiaries (as the Assumptions context requires). • This presentation does not include any express or implied prices at which Woodside will buy or sell financial products. • Unless otherwise indicated, the targets set out in this presentation have been estimated on the basis of a variety of economic assumptions including: (1) US$70/bbl Brent long-term oil price (2022 real terms, inflated at 2.0%); (2) currently • A securities rating is not a recommendation to buy, sell or hold securities and may be subject to revision or withdrawal at sanctioned projects being delivered in accordance with their current project schedules; and (3) applicable growth any time. opportunities being sanctioned and delivered in accordance with the target schedules provided in this presentation. 3
Delivering core business, growth projects and returns Reliable operating performance from global portfolio and 1 NET PROFIT AFTER TAX major turnarounds successfully completed $ 1.7 6% Continued execution of Sangomar and Scarborough 2 billion and final investment decision taken on Trion earnings per share of 92 US cps and 2 underlying net profit after tax of $1.9 billion 1 INTERIM DIVIDEND, FULLY 3 Agreed sale of 10% interest in Scarborough FRANKED Strong and flexible balance sheet with high liquidity and 4 80 27% low gearing, supporting near term growth US cps 80% payout of underlying net profit after tax 5 Returning value to shareholders and governments 1. Subsequent to the period. Completion of the transaction is subject to conditions precedent including Foreign Investment Review Board approval, National Offshore Petroleum Titles Administrator approvals and Western Australian Government approvals. 4 2. Non-IFRS financial measure. Net profit after tax excluding any exceptional items.
Strong operational performance and financial outcomes OPERATIONAL PERFORMANCE FINANCIAL OUTCOMES 2 TOTAL RECORDABLE INJURY RATE OPERATING REVENUE EBITDA PRODUCTION VOLUME $ 91.3 7.4 4.9 1.72 66% 27% 23% per million work hours MMboe billion billion Tragic fatality on North Rankin, strong Contribution from former BHPP assets Record H1 operating revenue, volume Record H1 EBITDA focus on improving personal safety from former BHPP assets performance CAPITAL AND EXPLORATION 2 1 LIQUIDITY REALISED PRICE LNG RELIABILITY 2 EXPENDITURE $ $ $ 7.5 97.7 74.0 2.8 5% 23% 82% 1% % per boe billion billion Low gearing of 8.2%, positioned for capital Planned turnaround undertaken on Reduced global oil and gas prices Investing in Scarborough and Sangomar investment through 2023 and 2024 Pluto LNG 1. Operated LNG facilities. 5 2. Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition.
Investing in Woodside’s future DELIVERING VALUE DELIVERING SUSTAINABILITY OUTCOMES NET EQUITY SCOPE 1 AND 2 2 ASSET DECARBONISATION PLANS SCARBOROUGH SELL-DOWN PROJECT DELIVERY GREENHOUSE GAS EMISSIONS Developed for all Sangomar and On track for 2025 Agreed sale of 10% Woodside and Scarborough net equity emissions interest in targeting first oil in mid 2024 former BHPP reduction target Scarborough and first LNG cargo in 2026 1 operated assets for ~$880m consideration respectively AUSTRALIAN TAX AND ROYALTIES CARBON CAPTURE AND STORAGE 3 FUTURE GROWTH INVESTING IN GROWTH CONTRIBUTION (CCS) Final investment Commenced front- Preparing for FID A$ decision (FID) taken end engineering 3.7 readiness 472% on Trion for H2OK and Woodside Solar design for South billion targeting first oil in 2028 East Australia CCS More than A$1 billion in PRRT paid in the 12 months to 30 June 2023 1. On completion of the transaction, expected in the first quarter of 2024, the estimated total consideration comprising the purchase price, reimbursed expenditure and escalation is approximately US$880 million. Completion of the transaction is subject to conditions precedent including Foreign Investment Review Board approval, National Offshore Petroleum Titles Administrator approvals and Western Australian Government approvals. 2. Woodside’s net emissions reduction targets are for net equity Scope 1 and 2 greenhouse gas emissions, with a targeted reduction of 15% by 2025, 30% by 2030, with an aspiration of net zero by 2050. The net emissions reduction targets are relative to a starting base representative of the gross annual average equity Scope 1 and 2 greenhouse gas emissions over 2016-2020 and may be adjusted (up or down) for potential equity changes in producing or sanctioned assets with a final investment decision prior to 2021. See sections 3.5 and 3.6 of Woodside’s Climate Report 2022 for further information regarding Woodside’s decarbonisation strategy, including plans and practices to support its emissions reduction target. 6 3. For further information on the Australian tax and royalties contribution refer to slide 30 of this presentation.
Challenging safety performance TRI and TRIR 1.80 35 2.00 1.74 1.72 30 Employee TRI 1.50 25 20 Fatality during inspection work on a caisson at the 0.90 0.88 24 1.00 19 Contractor TRI 15 North Rankin Complex 10 15 0.50 11 TRIR per 8 5 million work 8 6 3 3 hours 2 0 0.00 Shared learnings from fatality with industry 2019 2020 2021 2022 H1 2023 1 Tier 1 or Tier 2 loss of primary containment process safety events Pluto internal combustion event classified as a Tier 1 As at 30 June 2023 loss of primary containment process safety event Tier 1 Tier 2 2 Key focus for H2 2023 is improving safety performance 1 1 1 2019 2020 2021 2022 H1 2023 7 1. A loss of primary containment process safety event occurred in Trinidad and Tobago subsequent to the period which is yet to be classified. Investigation and safety checks are ongoing.
Operational performance North West Shelf Project Pluto LNG Other Australia Gulf of Mexico/ Trinidad & Tobago § LNG reliability of 99.9% § Completed planned five-yearly § First production achieved at § LNG reliability of 97.6% achieved in the five months Ngujima-Yin FPSO the Argos platform for Mad 1 prior to turnaround maintenance Dog Phase 2 § 5.4 MMboe of gas processed through Interconnector § Major turnaround completed § Enfield plug and abandonment § Successful appraisal well on onshore and offshore campaign continued with eight drilled in the south-west § On track to receive Waitsia facilities wells permanently plugged part of the Mad Dog field gas for processing § Pluto Remote Operations § Nganhurra riser turret mooring § Wells completed on Shenzi § Progressing negotiation of Centre in Perth fully decommissioning Environment North, first oil expected in key commercial terms to operational Plan approved in July 2023 2023 support Browse to NWS development concept § Installed electrical tie-in § Awarded all major contracts for points supporting potential decommissioning of Enfield, utilisation of solar energy Griffin, Stybarrow and Echo Yodel subsea infrastructure 8 1. Floating, production, storage and offloading (FPSO).
Returning value to shareholders through a period of high investment Interim and final dividend (US cps) 144 Fully franked interim dividend of 80 US cps and 109 1 105 annualised dividend yield of 6.9% 33 80 80% payout ratio and interim dividend payment value of $1.5 billion 76 55 Balanced cash flow and funding requirements 36 30 26 12 Disciplined capital management supporting strong dividends and growth 2019 2020 2021 2022 H1 2023 2 Interim dividend US cps Final dividend US cps BHP merger completion payment 1. Annualised yield based on interim dividend only. Woodside’s closing share price on 30 June 2023 was A$34.44 and the AUD/USD exchange rate was 0.67. 9 2. Interim 2022 fully franked dividend of 109 US cps consisted of an ordinary dividend component of 76 US cps and an additional dividend component relating to the BHP merger completion payment of 33 US cps.
Prices normalising following 2022 volatility Oil and gas prices 160 90 120 60 Price environment reflective of economic headwinds and high gas storage levels in Europe 80 2023 has highlighted a continued focus on energy security 30 40 with a number of long-term LNG contracts being signed in the market 0 0 2021 2022 2023 Asian spot LNG price (JKM, RHS) Dated Brent oil price (LHS) Monthly Japan Customs-cleared Crude oil price (JCC, LHS) 10 US$/bbl January March May July September November January March May July September November January March May US$/MMBtu
Robust prices relative to five year average 2 Average realised price 108 96 80 Portfolio actively positioned to realise benefits of trading activities 66 65 74 1 31% year-to-date gas hub exposure 51 40 45 Revised full-year 2023 gas hub exposure guidance 36 1 between 27 – 33% H1 2019 H1 2020 H1 2021 H1 2022 H1 2023 Volume weighted average realised price Average annual dated Brent 1. Gas hub exposure, which is the proportion of produced equity LNG volumes expected to be sold on gas hub indices such as JKM, TTF and UK National Balancing Point (excluding Henry Hub). 11 2. Average realised price represents weighted average realised price for all sales, including purchased volumes. $/boe
Robust LNG outlook; Scarborough expected online at opportune time 3 Global LNG supply and demand gap 800 Fine balance between expected supply and demand in Demand near-term Scarborough first cargo 600 Natural gas expected to play sustained role through the 1 energy transition 400 Under construction Natural gas can provide firming capacity for renewables electricity and is also used in a wide range of other sectors including potentially hard-to-abate sectors 200 Operational Woodside's portfolio weighted to gas; well positioned 2 for energy transition 0 2015 2019 2023 2027 2031 2035 2039 2043 2047 1. For further information on the role of oil and gas usage through the energy transition, refer to section 2.2 in Woodside’s Climate Report 2022. 2. ~70% gas per year-to-date production as identified in Woodside’s Second Quarter Report 2022. 12 3. Source: Wood Mackenzie LNG Tool – June 2023. mtpa
Sangomar – 88% complete, targeting first oil mid-2024 H1 2023 HIGHLIGHTS § Completed installation and testing of rigid flowlines § Completed 12 of 23 wells, with 11 wells partially complete § Progressed the subsea installation campaign, now 76% complete FPSO Léopold Sédar Senghor Subsea package H2 2023 FOCUS AREAS § Complete FPSO remedial work and pre-commissioning for sail away § Complete subsea installation § Continue development drilling campaign § Advance operational readiness activities Subsea installation campaign FPSO turret 13
Scarborough – 38% complete, targeting first LNG 2026 H1 2023 HIGHLIGHTS § Completed construction accommodation village § Completed pipeline manufacturing 1 § Agreed sell-down of 10% Scarborough interest (upstream) to LNG Japan § Scarborough Trunkline Installation (State Waters) Environment Plan accepted by the WA Government 2 § Marine Seismic Survey Environment Plan accepted by NOPSEMA, subject to conditions Pluto Train 2 site H2 2023 FOCUS AREAS § Progress Pluto Train 2 module fabrication and site works § Continue pipeline insulation coating § Continue construction of topsides and hull for the floating production unit (FPU) § Continue engagement with the regulator regarding Commonwealth Environment Plans KEY PROJECT RISK § Approval of outstanding Commonwealth Environment Plans (SURF, Trunkline and Module yard 3 Drilling & Completions) 1. Subsequent to the period. Completion of the transaction is subject to conditions precedent including Foreign Investment Review Board approval, National Offshore Petroleum Titles Administrator approvals and Western Australian Government approvals. 2. National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA). Occurred subsequent to the period in July 2023. The Environmental Defenders Office on behalf of Ms Raelene Cooper filed a challenge regarding the Seismic Environment Plan in the Victorian Federal Court in August 2023. 14 3. Subsea, umbilicals, risers and flowlines (SURF). The formal Environment Plan title names are Subsea Infrastructure Installation (SURF), Seabed Intervention and Trunkline Installation (Trunkline), and Drilling & Completions.
Trion – FID taken, targeting first oil 2028 H1 2023 HIGHLIGHTS § Final investment decision taken by Woodside 1 § Field development plan (FDP) approved by Joint Venture § FPU engineering, procurement and construction contract executed with Hyundai Heavy Industries 2 § Drilling rig, FPU and floating, storage and offloading installation contracts awarded § Reduced expected Trion carbon intensity to 11.8kg CO -e/boe over the life of field through 2 design out initiatives H2 2023 FOCUS AREAS § Receive approval of the FDP from regulator Trion FPU concept image 3 § Progress detailed engineering and procurement across FPU, FSO and SURF § Initiate preparations for regulatory permits for execution activities § Continue to award key contracts 1. The development remains subject to regulatory approval of the FDP. 2. Subsequent to the period. 15 3. Subsea, umbilicals, risers and flowlines (SURF).
Momentum building in the global hydrogen market 1 Low carbon hydrogen demand outlook (mtpa) 20 250 10 200 Other Rise in national strategies, technology roadmaps and Methanol 0 150 fiscal incentives Other Industry Shipping 100 Steel The US Inflation Reduction Act has been a global Road Transport 50 catalyst Ammonia Power 0 2023 2028 2033 2038 2043 2048 Increase in demand-side subsidies Woodside’s approach Initiate market development and maintain capital discipline Collaboration across the value chain is critical to the hydrogen market evolution Collaborate with De-risk technology Build portfolio and customers barriers capability 16 1. In addition, currently there is ~100 mtpa of existing global hydrogen demand, fossil fuel based. Source: WoodMac Energy Transition Tool & Lens Hydrogen, August 2023. 2023 2024 2025 2026 2027 2028 2029 2030
Portfolio of new energy opportunities Woodside Solar Heliogen Proposed solar facility expected to initially supply approximately 50 MW of solar energy Initial 5 MW concentrated solar energy to Pluto LNG. Key electrical tie-in points system to prove concept of energy installed during the 2023 Pluto turnaround delivery with nearly 24/7 availability. Potential deployment to support our operations Houston Southern Green Hydrogen Proposal for renewable ammonia production facility, targeting up to 1,400 tpd of ammonia Perth H2Perth H2OK Proposal for a world-scale hydrogen and H2Tas Proposed hydrogen facility producing up to 60 ammonia production facility. Land secured in tonnes per day of liquid hydrogen. Strategically industrial precinct with access to Asian and Proposal for renewable hydrogen located to service heavy duty transport and Australian markets production for export as ammonia emerging markets to Asian markets 17 Conceptual images only, not to scale. Proposed facilities are subject to project approvals, regulatory approvals, commercial agreements and market demand.
H2OK progressing towards FID readiness H2 2023 H1 2023 HIGHLIGHTS § Purchased 94 acres of land in the Westport Industrial Park in Ardmore, Oklahoma, for the proposed H2OK facility 1 § Construction bids received in July, and under review H2 2023 FOCUS AREAS § Execute agreements for power and water supply § Progress customer offtake discussions H2OK concept image § Confirm impact of federal and state incentives 18 1. Subsequent to the period.
Building CCS options Carbon capture and storage (CCS) portfolio options Catalysts for de-risking Carbon capture technology Browse CCS Bonaparte CCS CCS included as base case for Collaboration with industry to develop business Government support; Browse development concept case for large-scale carbon capture utilisation incentives and regulation and storage (CCUS) hub Large reservoir storage Northern Carnarvon Basin CCS capacity South East Australia CCS Potential for third party CO storage in 2 FEED commenced in H1 2023 for potential CO 2 the depleted Angel gas field End to end value-chain storage in the Gippsland Basin development § Woodside CCS locations based on extensive subsurface experience Location and proximity to CO sources 2 Pathways to § Collaborating and partnering with major operators with CCS Capability overcome CCS experience challenges § Stable legislation, regulatory and policy frameworks with path to Government support approvals 19
Progressing asset decarbonisation Avoiding and reducing emissions are Woodside’s priority Delivering emissions reductions pathways 1 Potential impact of asset decarbonisation planning § Woodside has a lower gross Scope 1 and 2 emissions 2 intensity than the global average of a comparable portfolio +300kt +340kt 8 Avoiding and reducing emissions at source decreases § Asset decarbonisation plans extended to merged portfolio use of carbon credits as offsets and identified an potential for an additional ~340kt CO -e 2 1 reduction in 2030 6 § Applied climate considerations to Trion FID 4 § Extended World Bank Zero Routine Flaring initiative to former BHPP assets 2 § Woodside leading Methane Guiding Principles (MGP) global initiative to reduce methane emissions in the supply and transport of LNG 0 2030 Gross equity emissions in Offset 2030 net equity scope 1&2 2030 gross equity Offset 2030 net equity Emissions to be abated by design out and operate out 2030 prior to Design Out As estimated in Climate As estimated in Climate As estimated after 2023 asset emissions target§ Building carbon credit portfolio through origination and emissions in 2030 Scope 1 and 2 Report 2021 Report 2022 decarbonisation plan As estimated after market purchases to deliver 2030 target; planting activities prior to design out emissions target As estimated in As estimated in 2023 asset Climate Report Climate Report commenced on ~5,600 hectares of land decarbonisation 2022 2021 plan 1. Potential impact of opportunities identified in asset decarbonisation plans assuming that all opportunities progress to execution, which is not certain and remains subject to further maturation of cost and engineering definition. Greenhouse gas quantities are estimated using engineering judgement by Woodside engineers. Annual estimations of asset decarbonisation quantities are not fully comparable due to changes in equity over the period. Quantities for 2021 and 2022 are displayed as per the Climate Report 2022, and all other emissions are estimated equity share across the whole Woodside portfolio (inclusive of the Scarborough equity sell down announced in August 2023). Indicative only, not guidance. 2. Woodside analysis, based on Woodside Scope 1 and 2 emissions data for 2022 relative to a comparable portfolio of LNG, conventional shelf and deepwater assets, as estimated by Wood Mackenzie. Refer to Figure 20, page 42, Woodside’s Climate 20 Report 2022. 2030 Scope 1 and 2 emissions (Mtpa CO -e) 2
FINANCIAL UPDATE Graham Tiver Chief Financial Officer and Executive Vice President 21
Strong earnings and balance sheet from expanded global portfolio HY23 HY22 Change $m Operating revenue 7,400 5,810 27% 1 $m EBITDA 4,888 3,971 23% Additional volume from former BHPP assets and Pluto- 1 $m EBIT 2,791 2,982 6% KGP Interconnector, impacted by lower prices and planned turnaround activities $m NPAT 1,740 1,640 6% 1,2 $m Underlying NPAT 1,896 1,819 4% $7.5 billion liquidity enabling investments in near-term 3 $m Operating cash flow 2,931 2,506 17% growth 3,4 $m Free cash flow 294 2,551 88% Delivering strong returns to shareholders whilst 1 $m Liquidity 7,509 7,915 5% maintaining balance sheet flexibility US cps Earnings per share 92 146 37% % Return on equity 9.7 10.1 4% US cps Half-year dividend 80 109 27% 1. Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. 2. Refer to slide 36 of this presentation for the list of specific items for HY23. 3. HY22 comparative has been restated due to the reclassification of purchases of shares and payments relating to employee share plans from cash flows from financing activities to cash flows from operating activities. 4. Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. For HY23, free cash flow of $0.3 billion includes the impact of collateral receipts of $332 million against hedging activities (included 22 in operating cash flow). For HY22, free cash flow includes the cash received on the acquisition of BHP Petroleum, including cash acquired of $1.082 billion.
Disciplined capital management Well positioned for major Capital management Resilient through the 1 2 3 capital investment through supports strong price cycle 2023 and 2024 dividends and growth Dividend Operating Investing 1 $ $ $ $ Net debt 1,2 3.2B 2.9B 1 1.5B 2.6B determined cash flow cash flow Special dividends Safe, reliable Dividend policy Investment Strong balance and low cost (minimum 50% Share buy-backs expenditure sheet payout ratio) operations CAPITAL Future investment Excess MANAGEMENT cash FRAMEWORK Maintain dividend based on NPAT Targeting 10-20% gearing Investment grade credit excluding non-recurring items, targeting through the cycle rating 50-80% payout ratio 4 3 8.2% BBB+/Baa1 80% payout ratio 80 US cps 1. Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. 2. Operating cash flow of $2.9 billion and free cash flow of $0.3 billion include the impact of collateral receipts of $332 million against hedging activities (included in operating cash flow). 3. Corporate debt credit ratings. BBB+ by S&P Global, Baa1 by Moody’s. 23 4. If added to the half-year financials, the 2023 interim dividend would have the effect of increasing the half year gearing to 12.1%.
Expanded portfolio offsetting lower prices and planned turnarounds 1 1,2 Operating revenue EBITDA Underlying NPAT 7.4 1.9 1.8 4.9 5.8 4.0 2.5 2.3 1.9 1.5 1.5 0.4 0.4 1.0 0.3 H1 2019 H1 2020 H1 2021 H1 2022 H1 2023 H1 2019 H1 2020 H1 2021 H1 2022 H1 2023 H1 2019 H1 2020 H1 2021 H1 2022 H1 2023 Higher revenue driven by additional volume from the former BHPP assets and contribution of the Pluto-KGP Interconnector Impacted by lower realised prices, planned major turnarounds and associated operating costs (including depreciation) from the former BHPP assets 1. Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. 24 2. 2023 NPAT adjustments include the post-tax impacts of the derecognition of Pluto PRRT DTA ($446m) and Pyrenees impairment ($29m) offset by the recognition of Trion DTA ($319m). $ billion $ billion $ billion
Investing in growth 1 2 Operating cash flow Investing cash flow Free cash flow 2.9 2.6 1.1 2.5 1.5 1.5 1.3 0.3 1.1 1.0 1.0 0.9 0.8 0.6 0.3 0.3 0.3 H1 2019 H1 2020 H1 2021 H1 2022 H1 2023 H1 2019 H1 2020 H1 2021 H1 2022 H1 2023 H1 2019 H1 2020 H1 2021 H1 2022 H1 2023 Benefit of GIP's additional contribution to Pluto Train 2 Proceeds of merger completion payment Increased cash generated from operations driven by contribution of former BHPP assets offset by higher income tax and PRRT payments Higher investing cash outflow due to capital expenditure on Scarborough and Sangomar. H1 2022 included cash received as part of the BHPP merger 1. For H1 2022 the investing cash flow excludes the cash received on the acquisition of BHP Petroleum, including cash acquired of $1.082 billion. 25 2. Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. $ billion $ billion $ billion
Cost performance impacted by planned turnarounds 2 Production cost Major turnarounds 84 413 Production cost (BHPP) Heritage Woodside costs remain in line with H1 2022 86 65 Production cost (WDS) 311 310 Full period contribution of former BHPP assets 224 225 218 changing cost mix H1 2019 H1 2020 H1 2021 H1 2022 H1 2023 2,3 Interconnector continues to drive value Unit production cost 8.8 Impact of major 0.9 7.3 3 7.2 turnarounds Completed planned major turnarounds on 1 1.7 Pluto LNG and Ngujima-Yin FPSO 4.9 4.5 UPC excluding major 7.9 turnarounds 7.2 5.6 4.9 Managing inflationary pressures 4.5 H1 2019 H1 2020 H1 2021 H1 2022 H1 2023 1. Ngujima-Yin FPSO resumed production subsequent to the period. 2. H1 2022 increased primarily as result of the Pluto-KGP Interconnector and the inclusion of the former BHPP assets. 26 3. Does not consider the volume loss impact associated with the major turnarounds. $/boe $ million
Maintained 80% cash margin in lower price environment 1 Cash margin Inclusion of additional five months BHPP revenue 1 CASH MARGIN Additional Interconnector cargoes Revenue impacted by planned Pluto and Ngujima-Yin 57.4$/boe turnarounds 73% PRODUCTION COSTS 80% 80% 82% 85% (Based on sales boe excluding purchased LNG) Cost of planned Pluto and Ngujima-Yin turnarounds 8.9$/boe 2 OTHER CASH COSTS 14% Royalties and excise from higher associated revenue 12% 13% 11% 8% 13% 5.2$/boe Shipping costs 8% 7% 7% 7% H1 2019 H1 2020 H1 2021 H1 2022 H1 2023 1. Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. 27 2. Other cash costs includes royalties, excise and levies, insurance, inventory movement, shipping and direct sales costs and other hydrocarbon costs.
Positioned to deliver strong shareholder returns and business priorities 1 Net debt and gearing 4.5 30% 3.9 3.8 4.0 25% 3.2 3.5 2.8 3.0 20% Target 10-20% Gearing and net debt increased in line with planned 2.5 gearing through 15% 1 2.0 capital expenditure the cycle 1.5 10% 1.0 0.6 Net debt 5% 0.5 Gearing (%) Low gearing of 8.2% and low cost of drawn debt of 0.0 0% FY 2019 FY 2020 FY 2021 FY 2022 H1 2023 2,3 4.0% provides balance sheet resilience 2 Balanced debt maturity profile 4 Credit ratings of BBB+ and Baa1 2.0 1.5 No significant near-term maturities 1.0 Undrawn Drawn 0.5 0.0 1. Non-IFRS financial measures. Refer to the glossary section of this presentation for the definition. 2. As at 30 June 2023. 3. If added to the half-year financials, the 2023 interim dividend would have the effect of increasing the half year gearing to 12.1%. 28 4. Corporate debt credit ratings. BBB+ by S&P Global, Baa1 by Moody’s. $ billion $ billion 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032
Maintaining strong liquidity through the cycle Continuing strong liquidity 10.2 Robust liquidity management to support near term growth and returns 7.5 7.0 6.7 6.1 Total forecast $6.0 – 6.5 billion dollars of capital Undrawn facilities expenditure in 2023 remains unchanged Cash Liquidity Scarborough sell-down proceeds, expected to be 1 received in Q1 2024, supporting liquidity Proactively manage the debt portfolio FY 2019 FY 2020 FY 2021 FY 2022 H1 2023 1. Completion of the transaction is subject to conditions precedent including Foreign Investment Review Board approval, National Offshore Petroleum Titles Administrator approvals and Western Australian Government 29 approvals. $ billion
Record A$3.7 billion paid in Australian tax and royalties in H1 2023 4 Australian tax contribution (paid in the period) 3.7 2.7 1 >A$1 billion in PRRT paid in the past 12 months A$2,850m | Corporate income tax 2 >US$300 million of foreign tax paid in H1 2023 3 Global all-in effective tax rate of 42% 0.7 0.7 0.7 A$366m | Petroleum resource rent tax A$317m | Federal royalties A$83m | Federal excise A$38m | Fringe benefits tax and payroll tax FY 2019 FY 2020 FY 2021 FY 2022 H1 2023 1. 12 months to 30 June 2023. 2. Includes Trinidad and Tobago production entitlements which are paid in-kind. 3. Total tax expense, royalties, excise, levies and other taxes, divided by profit before such taxes, royalties, excise, levies and other taxes excluding. Excludes the recognition of the Trion DTA and derecognition of the Pluto PRRT DTA. With these included, the global all-in effective tax rate would be 46%. 30 4. Figures are reported on a cash basis (net of any refunds received, for example, refunds of tax overpaid in prior periods) and are rounded to the nearest million. A$ billion
OUTLOOK Meg O’Neill Chief Executive Officer and Managing Director 31
The investment case – a global energy supplier DISCIPLINED CAPITAL HIGH QUALITY POSITIONED FOR THE PORTFOLIO MANAGEMENT ENERGY TRANSITION Framework established to optimise value Agile, flexible and adaptable as the Scale, diversification and resilience and shareholder returns world’s energy mix evolves to deliver enduring value Resilient cash flow Advantaged locations and markets On track to deliver net emissions reduction 1 History of strong dividends targets Conventional asset base weighted to LNG Clear capital allocation and Progressing new energy opportunities Major growth projects in execution capital management frameworks Customer-led and scalable Pipeline of opportunities Strong balance sheet Safe | Reliable | Low cost | Lower carbon | High cash generation Further information as to Woodside’s climate strategy, including references to “lower carbon” as part of that strategy, is set out in Woodside’s Climate Report 2022 available on the Woodside website at https://www.woodside.com/sustainability/climate-change. 1. Woodside’s net emissions reduction targets are for net equity Scope 1 and 2 greenhouse gas emissions, with a targeted reduction of 15% by 2025, 30% by 2030, with an aspiration of net zero by 2050. The net emissions reduction targets are relative to a starting base of the gross annual average equity Scope 1 and 2 greenhouse gas emissions over 2016-2020. The baseline will be adjusted for the assets acquired through the merger with BHP Petroleum and may be adjusted (up or down) for potential equity changes in producing or sanctioned assets with an FID prior to 2021. See sections 3.5 and 3.6 of Woodside’s Climate Report 2022 for further information regarding Woodside's decarbonisation strategy, including plans and practices to support its 32 emissions reduction target. In 2022, Woodside delivered net equity Scope 1 and 2 greenhouse gas emissions reductions of 11% below the starting base, which was adjusted to include the assets acquired through the merger with BHP Petroleum.
Disciplined capital allocation OIL GAS NEW ENERGY OFFSHORE PIPELINE LNG DIVERSIFIED Generate high returns to fund New energy products and lower Leveraging infrastructure to monetise undeveloped diversified growth, focusing on carbon services to reduce customers’ FOCUS gas, including optionality for hydrogen 1 high quality resources emissions; hydrogen, ammonia, CCUS Stable long-term cash High cash generation Long-term cash flow Developing market flow profile Shorter payback period Strong forecast demand Lower capital requirement CHARACTERISTICS Resilient to commodity Quick to market Upside potential Lower risk profile pricing IRR > 15% IRR > 12% IRR > 10% OPPORTUNITY 2 2 2 TARGETS Payback within 5 years Payback within 7 years Payback within 10 years EMISSIONS 3 30% net emissions reduction target by 2030, net zero aspiration by 2050 or sooner REDUCTIONS 1. CCUS refers to carbon capture utilisation and storage. 2. Payback refers to RFSU + X years. 3. Woodside’s net emissions reduction targets are for net equity Scope 1 and 2 greenhouse gas emissions, with a targeted reduction of 15% by 2025, 30% by 2030, with an aspiration of net zero by 2050. The net emissions reduction targets are relative to a starting base representative of the gross annual average equity Scope 1 and 2 greenhouse gas emissions over 2016-2020 and may be adjusted (up or down) for potential equity changes in producing or sanctioned assets with a final investment decision prior to 2021. 33 Please refer to the Glossary starting on page 59 and the section on decarbonisation strategy starting on page 28 of Woodside’s Climate Report 2022 for further information on the definition and calculation of Scope 1 and 2 net equity greenhouse gas emissions.
Clear priorities to optimise value and drive shareholder returns CORE BUSINESS MAJOR PROJECTS SUSTAINABLE FUTURE Complete pre-commissioning and remedial work on Sangomar FPSO Execute core business safely, reliably and Prepare for FID readiness at H2OK and Woodside Solar cost-efficiently with reduced emissions Progress environmental plans and execution of Scarborough Improve safety performance Mature new energy portfolio options Execute major contracts for Trion 34
ANNEXURE 35
Net profit after tax reconciliation INTERIM DIVIDEND, FULLY SALES COST OF SALES GENERAL, ADMINISTRATIVE, TAX AND OTHER FRANKED Volume from former BHPP Managing underlying Fully franked interim One-off transactions and tax impacts assets offset by lower realised inflationary pressures dividend of 80 US cps prices and impact of turnarounds 2,532 (64) (500) (1,020) Additional five Lower realised months of prices across former BHPP price markers assets and 156 1,896 planned 85 1,740 (114) 186 (878) 1,640 turnarounds (364) 305 (68) Derecognition of Addition of Pluto PRRT DTA former BHPP Includes Pyrenees ($446m) assets recognition of impairment recognition of Trion Train 2 sell Reduced Trion DTA DTA (-$319m), down in merger offset by Pyrenees H1 2022 transaction Additional derecognition impairment ($29m) costs volume of Pluto PRRT from former DTA BHPP assets 2022 H1 Sales revenue - Sales revenue - Sales revenue - Cost of Oil and gas Other cost of Other income General, Impairment Income tax and Other expenses 2023 H1 2023 H1 NPAT 2023 H1 reported NPAT price volume (former volume (other) production properties sales administrative losses PRRT expense reported NPAT adjustments underlying 1 BHPP assets) depreciation and other costs NPAT and amortisation 36 1. Non-IFRS financial measure. Net profit after tax excluding any exceptional items. $ million
2023 full-year guidance Production guidance (unchanged) • Woodside’s production guidance is 180 – 190 MMboe • Production guidance is inclusive of the planned North West Shelf LNG Train 1 major turnaround in Q3 2023, duration approximately 4 weeks 1 Investment expenditure guidance (unchanged) • Woodside’s exploration expenditure guidance is $0.3 – 0.4 billion • Woodside’s capital expenditure guidance is $6.0 – 6.5 billion Gas hub exposure (revised) 2 • Woodside’s updated gas hub exposure guidance for the portfolio, as a % of produced LNG, is 27 – 33% 1. Capital expenditure includes capital additions on oil and gas properties and evaluation capitalised. Exploration expenditure includes exploration and evaluation expenditure less amortisation of licence acquisition costs and prior year exploration expense written off. 37 2. Gas hub exposure is the proportion of produced equity LNG volumes expected to be sold on gas hub indices such as JKM, TTF and UK National Balancing Point (excluding Henry Hub).
Asset tables Depreciation and 1 1 3 Operating revenue EBITDA EBIT Capital expenditure Production costs 2 Asset amortisation $ million $ million $ million $ million $ million $ million Australia 1,917 1,549 406 1,143 52 99 North West Shelf 1,834 1,608 412 1,196 122 231 Pluto 511 451 221 230 25 33 Wheatstone 558 434 201 233 28 114 Bass Strait 99 83 29 54 9 12 Macedon 139 105 139 (34) 66 32 Pyrenees 96 21 53 (32) 2 70 Ngujima-Yin 55 29 9 20 1 23 Okha - 2 - 2 1,174 - Scarborough - (17) - (17) 10 - Other Australia Total Australia 5,209 4,265 1,470 2,795 1,489 614 International 243 196 75 121 2 21 Trinidad & Tobago 401 307 170 137 94 77 Atlantis 399 326 214 112 130 64 Shenzi 4 184 144 75 69 132 31 Mad Dog - (1) - (1) 8 - Trion - (2) 1 (3) 600 - Sangomar 9 (139) 23 (162) 114 - Other International Total International 1,236 831 558 273 1,080 193 Marketing 955 199 34 165 - - Corporate/Other - (407) 35 (442) 115 - Total 7,400 4,888 2,097 2,791 2,684 807 1. Non-IFRS financial measures. Refer to the glossary section of this presentation for the definition. 2. Includes exploration permit cost amortisation, impairment losses and impairment reversals. 38 3. Includes exploration capitalised and excludes the effect of Global Infrastructure Partners’ (GIP) additional contribution to Pluto Train 2. 4. Includes Mad Dog and Mad Dog Phase 2.
Realised price 4 5 Products Units H1 2023 H1 2022 Variance 1 LNG produced $/boe 88 89 (1) 2 LNG traded $/boe 90 140 (50) Pipeline gas $/boe 38 52 (14) Oil and condensate $/boe 75 114 (39) NGLs $/boe 47 48 (1) Average realised price $/boe 74 96 (22) Average Dated Brent $/bbl 80 108 JCC (lagged three months) $/bbl 94 83 JKM $/MMBtu 19 31 WTI $/bbl 75 101 3 TTF $/MMBtu 19 33 1. Realised prices include the impact of periodic adjustments reflecting the arrangements governing Wheatstone LNG sales. 2. Excludes any additional benefit attributed to produced LNG through third-party trading activities. 3. TTF is converted from EUR/MWh to US$/MMBtu using published exchange rates and conversion factors. 4. HY22 realised price incorporates the updated boe conversion factors. 39 5. Minor differences due to rounding.
Corporate performance H1 2023 H1 2022 Production volume MMboe 91.3 54.9 Operating revenue $ million 7,400 5,810 1 EBITDA $ million 4,888 3,971 1 EBIT $ million 2,791 2,982 Net finance costs $ million 37 55 Tax expense $ million 1,062 1,248 Non-controlling interest $ million 26 39 NPAT $ million 1,740 1,640 40 1. Non-IFRS financial measures. Refer to the glossary section of this presentation for the definition.
Glossary Woodside sets its Scope 1 and 2 greenhouse gas emissions reduction targets on an equity basis. This $, $m, $B US dollar unless otherwise stated, millions of dollars, billions of dollars ensures that the scope of its emissions reduction targets is aligned with its economic interest in its Equity greenhouse gas emissions investments. Equity emissions reflect the greenhouse gas emissions from operations according to A$, AUD Australian dollar Woodside’s share of equity in the operation. Its equity share of an operation reflects its economic interest 2 in the operation, which is the extent of rights it has to the risks and rewards flowing from the operation Woodside uses this term to describe an aspiration to seek the achievement of an outcome but where Aspiration achievement of the outcome is subject to material uncertainties and contingencies such that Woodside Exploration expenditure includes exploration and evaluation expenditure less amortisation of licence Exploration expenditure considers there is not yet a suitable defined plan or pathway to achieve that outcome. acquisition costs and prior year exploration expense written off Bcf Billion cubic feet FDP Field development plan Woodside Energy Global Holdings Pty Ltd ACN 006 923 897 (formerly known as BHP Petroleum FEED Front-end engineering design International Pty Ltd) and, unless context otherwise requires, its subsidiaries. References to “Woodside BHP Petroleum or BHPP Energy Global Holdings Pty Ltd” or “BHP Petroleum International Pty Ltd” are references to Woodside FID Final investment decision Energy Global Holdings Pty Ltd ACN 006 923 897 (formerly known as BHP Petroleum International Pty FPSO Floating production storage and offloading Ltd) excluding its subsidiaries. Barrel of oil equivalent, thousand barrels of oil equivalent, million barrels of oil equivalent, billion FPU Floating production unit boe, kboe, MMboe, Bboe barrels of oil equivalent Free cash flow Cash flow from operating activities less cash flow from investing activities Capital expenditure Includes capital additions on oil and gas properties and evaluation capitalised Gearing Net debt divided by net debt and equity attributable to the equity holders of the parent Revenue from sale of produced hydrocarbons less production costs, royalties, excise and levies, The seven greenhouse gases listed in the Kyoto Protocol are: carbon dioxide (CO ); methane (CH ); nitrous 2 4 insurance, inventory movement, shipping and direct sales costs and other hydrocarbon costs; divided Cash margin GHG or greenhouse gas oxide (N O); hydrofluorocarbons (HFCs); nitrogen trifluoride (NF ); perfluorocarbons (PFCs); and sulphur 2 3 by revenue from the sale of produced hydrocarbons (sales volume). Excludes exploration and hexafluoride (SF ) 6 evaluation, general administrative and other costs, depreciation and amortisation, PRRT and income tax Investing cash flow Cash flow from investing activities CCS Carbon capture and storage IRR Internal rate of return CCU Carbon capture and utilisation The Japan customs-cleared crude is the average price of customs-cleared crude oil imports into Japan as CCUS Carbon capture, utilisation and storage JCC reported in customs statistics (also known as ‘Japanese crude cocktail’) and is used as a reference price for Methane CH 4 long-term supply LNG contracts CO Carbon dioxide 2 Japan Korea Marker is the North-east Asian spot price index for LNG delivered ex-ship to Japan, South JKM Korea, China and Taiwan. CO2 equivalent. The universal unit of measurement to indicate the global warming potential of each of the seven greenhouse gases, expressed in terms of the global warming potential of one unit of carbon CO -e JV Joint venture 2 dioxide. It is used to evaluate releasing (or avoiding releasing) any greenhouse gas against a common 1 basis KGP Karratha Gas Plant Conventional resources exist in porous and permeable rock with pressure equilibrium. The Liquidity Cash and undrawn facilities Conventional hydrocarbons are trapped in discrete accumulations related local geological structure feature and/or LNG Liquefied natural gas stratigraphic condition Woodside uses this term to describe the characteristic of having lower levels of associated potential GHG cps Cents per share Lower carbon emissions when compared to historical and/or current conventions or analogues, for example relating to Woodside uses this term to describe activities or pathways that have the effect of moving towards a an otherwise similar resource, process, production facility, product or service, or activity Decarbonisation state that is lower carbon, as defined in this glossary A lower carbon economy is an economy that produces lower levels of greenhouse gas emissions relative Lower carbon economy DTA Deferred tax asset to today’s economy Lower carbon energy provider Woodside uses this term to describe its aspiration to develop a lower carbon portfolio EBIT Calculated as a profit before income tax, PRRT and net finance costs Calculated as profit before income tax, PRRT, net finance costs, depreciation and amortisation, For Woodside, a lower carbon portfolio is one from which the net equity scope 1 and 2 greenhouse gas EBITDA impairment losses, impairment reversals emissions, which includes the use of offsets, are being reduced towards targets, and into which new Lower carbon portfolio energy products and lower carbon services are planned to be introduced as a complement to existing and new investments in oil and gas. Woodside’s Climate Policy sets out the principles that we believe will assist us achieve this aim 1. See IFRS Foundation 2021: Climate Related Disclosures Prototype. Appendix A. The IFRS published a further consultation document subsequent to the 2021 prototype. As it did not contain a updated definition of Paris-Aligned scenarios Woodside has retained use of the previous edition. 41 2. World Resources Institute and World Business Council for Sustainable Development 2004. “GHG Protocol: a corporate accounting and reporting standard”.
Glossary Woodside uses this term to describe technologies, such as CCUS or offsets, that may be capable of PRRT Petroleum resource rent tax Lower carbon services reducing the net greenhouse gas emissions of our customers RFSU Ready for start-up MGP Methane Guiding Principles Direct GHG emissions. These occur from sources that are owned or controlled by the company, for example, emissions from combustion in owned or controlled boilers, furnaces, vehicles, etc.; emissions MMbbl Million barrels from chemical production in owned or controlled process equipment. Woodside estimates greenhouse MMBtu Million British thermal units Scope 1 greenhouse gas gas emissions, energy values and global warming potentials are estimated in accordance with the relevant emissions reporting regulations in the jurisdiction where the emissions occur (e.g. Australian National Greenhouse Mtpa Million tonnes per annum and Energy Reporting (NGER), US EPA Greenhouse Gas Reporting Program (GHGRP)). Australian regulatory reporting principles have been used for emissions in jurisdictions where regulations do not yet MW Megawatt 3 exist MWh Megawatt hour Electricity indirect GHG emissions. Scope 2 accounts for GHG emissions from the generation of purchased electricity consumed by the company. Purchased electricity is defined as electricity that is purchased or Net debt Interest-bearing liabilities and lease liabilities less cash and cash equivalents otherwise brought into the organisational boundary of the company. Scope 2 emissions physically occur Net equity Scope 1 and 2 Scope 2 greenhouse gas at the facility where electricity is generated. Woodside estimates greenhouse gas emissions, energy values Woodside’s equity share of net Scope 1 and 2 greenhouse gas emissions 1 greenhouse gas emissions emissions and global warming potentials are estimated in accordance with the relevant reporting regulations in the jurisdiction where the emissions occur (e.g. Australian National Greenhouse and Energy Reporting (NGER), Net zero emissions are achieved when anthropogenic emissions of greenhouse gases to the US EPA Greenhouse Gas Reporting Program (GHGRP)). Australian regulatory reporting principles have atmosphere are balanced by anthropogenic removals over a specified period. Where multiple 3 been used for emissions in jurisdictions where regulations do not yet exist Net zero greenhouse gases are involved, the quantification of net zero emissions depends on the climate metric chosen to compare emissions of different gases (such as global warming potential, global temperature Other indirect GHG emissions. Scope 3 is a reporting category that allows for the treatment of all other 2 change potential, and others, as well as the chosen time horizon) indirect emissions. Scope 3 emissions are a consequence of the activities of the company, but occur from Scope 3 greenhouse gas sources not owned or controlled by the company. Some examples of Scope 3 activities are extraction and Woodside uses this term to describe energy technologies, such as hydrogen or ammonia, that are emissions production of purchased materials; transportation of purchased fuels; and use of sold products and New energy emerging in scale but which are expected to grow during the energy transition due to having lower services. Please refer to the data table on page 58 of the Climate Report 2022 for further information on greenhouse gas emissions at the point of use than conventional fossil fuels 3 the Scope 3 emissions categories reported by Woodside NGLs Natural gas liquids SURF Subsea, umbilicals, risers and flowlines (SURF) NOPSEMA National Offshore Petroleum Safety and Environmental Management Authority In the context of Woodside’s Climate strategy, Woodside uses this term to describe an intention to seek Target the achievement of an outcome, where Woodside considers that it has developed a suitably defined plan NPAT Net profit after tax or pathway to achieve that outcome NWS North West Shelf TTF Title transfer facility The compensation for an entity’s greenhouse gas emissions within its scope by achieving an equivalent Offsets TRI Total recordable injuries amount of emission reductions or removals outside the boundary or value chain of that entity TRIR Total recordable injury rate Operating cash flow Cash flow from operating activities Underlying NPAT Net profit after tax excluding any exceptional items Oil and gas joint venture participants will typically appoint one company as the operator, which will hold the contractual authority to manage joint venture activities on behalf of the joint venture Unit production cost or UPC Production cost divided by production volume Operated and participants. Where Woodside is the operator of a joint venture in which it holds an equity share, this non-operated report refers to that joint venture as being operated. Where another company is the operator of a joint USD United States dollar venture in which Woodside holds an equity share, this report refers to that joint venture as being non- Woodside Woodside Energy Group Ltd ACN 004 898 962 or its applicable subsidiaries operated YTD Year to date An unplanned or uncontrolled loss of primary containment (LOPC) of any material including non-toxic Process safety event (Tier 1 and and nonflammable materials from a process, or an undesired event or condition. Process safety events Tier 2) are classified as Tier 1 – LOPC of greatest consequence or Tier 2 – LOPC of lesser consequence. As defined by American Petroleum Institute (API) recommended practice 754 1. Woodside has set its Scope 1 and 2 greenhouse gas emissions reduction targets on a net basis, allowing for both direct emissions reductions from its operations and emissions reductions achieved from the use of offsets. Net greenhouse gas emissions are equal to an entity’s gross greenhouse gas emissions reduced by the number of retired carbon credits. 2. IPCC, 2018: Annex I: Glossary [Matthews, J.B.R. (ed.)]. In: Global Warming of 1.5°C. An IPCC Special Report on the impacts of global warming of 1.5°C above pre-industrial levels and related global greenhouse gas emission pathways, in the context of strengthening the global response to the threat of climate change, sustainable development, and efforts to eradicate poverty [Masson-Delmotte, V., P. Zhai, H.-O. Pörtner, D. Roberts, J. Skea, P.R. Shukla, A. Pirani, W. Moufouma-Okia, C. Péan, R. Pidcock, S. Connors, J.B.R. Matthews, Y. Chen, X. Zhou, M.I. Gomis, E. Lonnoy, T. Maycock, M. Tignor, and T. Waterfield (eds.)]. In Press. Page 555. 42 3. World Resources Institute and World Business Council for Sustainable Development 2004. “GHG Protocol: a corporate accounting and reporting standard”.
Head Office: Woodside Energy Group Ltd Mia Yellagonga 11 Mount Street Perth WA 6000 Postal Address: GPO Box D188 Perth WA 6840 Australia T: +61 8 9348 4000 F: +61 8 9214 2777 E: companyinfo@woodside.com Woodside Energy Group Ltd ABN 55 004 898 962 woodside.com