Announcement PDF AUSTRALIS OIL & GAS LIMITED ABN 34 609 262 937 Level 1, 162 Grand Boulevard Joondalup WA 6027 • PO Box 8225 Subiaco East WA 6008 T +61 (8) 9220 8700 • F +61 (8) 9220 8799 www.australisoil.com For Immediate Release ASX Announcement 19 August 2026 First Half 2026 Financial Report Australis Oil & Gas Ltd (“Australis” or “Company”) is pleased to provide its consolidated financial results for the half year ended 30 June 2026. As announced at the end of 2025, Australis closed on two separate but strategically related transactions that together delivered on many of the key near-term objectives of the Company. Please refer to ASX announcements on 26 November 2025 and 31 December 2025 for further details. During the six-month reporting period the Australis team worked with counterparts at the Development Partner across multiple disciplines and as a result preparatory work for the permitting of the first wells in the Carry Program and detailed planning and completion designs commenced. The permit for the Initial Test Well under the Carry Program, the Willson 1H, has been granted and work has commenced on securing a spud date during Q4 2026 which will be determined by rig availability. Australis will be the designated operator of the Willson 1H and has retained the operational staffing levels required to meet this obligation together with the necessary contracted technical expertise. In addition, leasing has commenced as part of the Initial Leasing Program and leasing within permitted units is progressing with the permit application process initiated for the second Carried Well, the Mathieu 1H. A summary of financial results for the period is as follows: (1) Including a hedge loss of ($0.06) and non-recurring prior period adjustment of ($0.19) for the activity period 2014 to 2025 as a result of ownership changes identified as two wells reached payout. *Field Netback and Adjusted EBITDA are considered non-IFRS measures. Please refer to Non-IFRS Financial Measures below. To learn more about this announcement and our asset please Click Here The Financial Statements and Appendix 4D for the six-month period ended 30 June 2026 are attached. This ASX announcement was authorised for release by the Australis Disclosure Committee. Financial Results for half year ended 30 June 2026 - (US$) Sales Volumes (WI) 9,200 bbls Sales Revenue (WI)(1) $0.5 million Average Realised Price (excluding hedges and prior period adjustment) $85/bbl Field Netback* ($0.1) million Adjusted EBITDA* $(2.6) million Net loss after taxation $(2.6) million Period end cash position $11.2 million For further information, please contact: Ian Lusted Managing Director Australis Oil & Gas Limited +61 8 9220 8700 Graham Dowland Finance Director Australis Oil & Gas Limited +61 8 9220 8700 To receive alerts for ASX announcements and the latest updates from Australis please visit our website www.australisoil.com or use the QR code and register your email address ABOUT AUSTRALIS Australis (ASX: ATS) is an ASX listed oil and gas company seeking to provide shareholders value and growth through the strategic development of its quality onshore oil and gas assets in the United States of America. The Company was formed by the founder and key executives of Aurora Oil & Gas Limited, a team with a demonstrated track record of creating and realising shareholder value. With approximately 47,300 net acres (84% HBP) within the production delineated core of the proven oil producing TMS, Australis retains significant upside potential with approximately 160 net future drilling locations. At year end 2025 Ryder Scott independently assessed the Australis acreage held at that time with 62 MMbbls of 2P + 2C recoverable volume including 165 Mbbls 2P producing reserves providing net field cash flow1,2. The contingent oil resource is only contingent on a qualifying development program and Australis will carry out a reassessment of its undeveloped reserve position when a development program is underway. GLOSSARY Unit Measure Unit Measure B Prefix – Billions bbl Barrel of oil MM Prefix – Millions boe Barrel of Oil equivalent (1bbl = 6 mscf) M or k Prefix – Thousands scf Standard cubic foot of gas /d Suffix – per day Bcf Billion cubic feet of gas Term Definition 1P Proved Developed Reserves (PDP + PDNP) 2P Probable Reserves 3P Possible Reserves AMI Area of Mutual Interest within the TMS Core where Australis has the right to participate with Development Partner at a 20% working interest in any new leases taken C Contingent Resources (1C/2C/3C equivalent to low/most likely/high) Carry Program The carried TMS development work program contemplated by the Development Transaction, pursuant to which Development Partner will carry Australis for a 20% working interest Development Partner A US listed independent oil and gas company with a multi-billion dollar enterprise value and active onshore development and exploration operations in multiple unconventional US basins Field Netback Oil and gas sales net of royalties, production and state taxes, inventory movements, hedging gains or losses and field-based production expenses but excludes depletion and depreciation Initial Leasing Program US$1 million lease program within the AMI under the Development Transaction where Australis is carried by the Development Partner for a 20% working interest Initial Test Well The first carried well to be drilled under the Development Transaction Net or NRI Company beneficial interest after royalties or burdens Net Acres Working Interest before deduction of royalties or burdens NPV(10) Net Present Value (@ discount rate) PDNP Proved Developed Not Producing Reserves PDP Proved Developed Producing Reserves Royalty Interest in a leasehold area providing the holder with the right to receive a share of production associated with the leasehold area TMS Tuscaloosa Marine Shale TMS Core The Australis designated productive core area of the TMS delineated by production history TMS Type Curve The history matched production performance of 15 wells drilled in the TMS by Encana in 2014. Corresponds to an average treated horizontal length of 7,200ft. Refer to the Appendix of the Australis Corporate Presentation WI Company beneficial interest before royalties WTI West Texas Intermediate oil benchmark price YE Year end Footnotes 1. Estimates from the independent Ryder Scott report, effective 31 December 2025 and dated 29 January 2026, which was initially disclosed in the announcement titled “Quarterly Activities and Annual Reserve Report’ issued on 30 January 2026 The report was prepared in accordance with the definitions and disclosure guidelines contained in the Society of Petroleum Engineers (SPE), World Petroleum Council (WPC), American Association of Petroleum Geologists (AAPG), and Society of Petroleum Evaluation Engineers (SPEE) Petroleum Resources Management (SPE- PRMS) as revised in June 2018. Ryder Scott generated their independent reserve and contingent resource estimates using deterministic methods. The achieved price and NPV(10) values quoted are for the project only, they do not include any impact from any oil price hedges that Australis had entered into at that time. Australis is not aware of any new information or data that materially affects the information included in the referenced announcement and all the material assumptions and technical parameters underpinning the estimates in the original announcement continue to apply and have not materially changed. 2. The figures quoted is the rounded arithmetic sum of the 2P reserve and 2C resource estimate as reported in the Ryder Scott reserve report dated 29 January 2026. That report included the following reserve and resource estimates of oil. The 1P, 2P and 3P figures provided are the arithmetic summation by category and are referenced to the individual well oil metering at each producing well location. The 1C, 2C and 3C figures provided are the arithmetic summation by category. Net Oil Reserves (Mbbls) Contingent Oil Resources (Mbbls) 1P 128 1C 19,709 2P 165 2C 62,156 3P 213 3C 112,498 Non-IFRS Financial Measures References are made within this report to certain financial measures that do not have a standardised meaning prescribed by International Financial Reporting Standards (IFRS). Such measures are neither required by, nor calculated in accordance with IFRS, and therefore are considered Non–IFRS financial measures. Field Netback and Adjusted EBITDA, as defined within the Glossary, are Non-IFRS financial measures commonly used in the oil and gas industry or financial measures that are relevant to Australis. Non-IFRS financial measures used by the Company may not be comparable with the calculation of similar measures by other companies. EBIT represents net income /(loss) for the period before income tax expense or benefit and finance costs. Adjusted EBITDA represents EBIT before depletion, depreciation and amortisation charges, expired lease write off and impairment expense. The following table reconciles net profit after tax to Adjusted EBITDA: 30 June 2026 US$’000 Net loss after tax (2,593) Adjustments: Net finance expenses (204) EBIT Depletion & Depreciation 195 Adjusted EBITDA (2,602) FIELD NETBACK Field Netback represents oil and gas sales net of royalties, production and state taxes, inventory movements, hedging gains or losses, field based production expenses but excludes depletion and depreciation. 30 June 2026 US$’000 Revenue (including hedging (loss)): 508 Royalties (153) Direct operating costs & taxes (496) Inventory adjustments (14) Field Netback (155) Forward Looking Statements This document may include forward looking statements. Forward looking statements include, but are not necessarily limited to, statements concerning Australis’ planned operation program and other statements that are not historic facts. When used in this document, the words such as “could”, “plan”, “estimate”, “expect”, “intend”, “may”, “potential”, “should” and similar expressions are forward looking statements. Although Australis believes its expectations reflected in these statements are reasonable, such statements involve risks and uncertainties, and no assurance can be given that actual results will be consistent with these forward-looking statements. AUSTRALIS OIL & GAS LIMITED ABN 34 609 262 937 Level 1, 162 Grand Boulevard Joondalup WA 6027 • PO Box 8225 Subiaco East WA 6008 T +61 (8) 9220 8700 • F +61 (8) 9220 8799 www.australisoil.com 19 August 2026 APPENDIX 4D HALF YEAR REPORT FOR THE PERIOD ENDED 30 JUNE 2026 Name of Entity: AUSTRALIS OIL & GAS LIMTED (ASX: ATS) ABN or equivalent company reference 34 609 262 937 This information and the Australis Oil & Gas Limited Interim Financial Report for the Half Year Ended 30 June 2026 should be read in conjunction with the Australis Oil & Gas Limited 2025 Annual Report (which contains the 2025 audited Financial Report). Results for Announcement to the Market Revenue from ordinary activities Decreased by 93%(1) from US$7.72 million for the half year ended 30 June 2025 to US$0.51 million for the half year ended 30 June 2026. Loss from ordinary activities after tax attributable to members Increased by 38%(1) from a loss of US$1.89 million for the half year ended 30 June 2025 to a loss of US$2.59 million for the half year ended 30 June 2026. Loss for the period attributable to members Increased by 38%(1) from a loss of US$1.89 million for the half year ended 30 June 2025 to a loss of US$2.59 million for the half year ended 30 June 2026.. An explanation of the results is included in the Interim Financial Report ended 30 June 2026 which can be found on the ASX website or the Australis website at www.australisoil.com (1) Comparisons are made to the financial results for the half year ended 30 June 2025. Dividends No dividends are proposed (2025: nil). Net Tangible Asset per Security 30 June 2026 30 June 2025 US$0.01 US$0.03 Changes in controlled entities There have been no changes in controlled entities during the half year ended 30 June 2026. This report is based on the consolidated half year financial statements for the half year ended 30 June 2026 which have been reviewed by BDO Audit Pty Ltd. AUSTRALIS OIL & GAS LIMITED ABN 34 609 262 937 CONSOLIDATED INTERIM FINANCIAL REPORT FOR THE HALF YEAR ENDED 30 JUNE 2026 ABN 34 609 262 937 2 Page Corporate directory 3 Directors’ report 4 Auditors’ independence declaration 10 Independent Auditor’s review report 11 Directors’ declaration 13 Consolidated statement of profit or loss and other comprehensive income 14 Consolidated statement of financial position 15 Consolidated statement of changes in equity 16 Consolidated statement of cash flows 17 Notes to the financial statements 18 ABN 34 609 262 937 Corporate directory 3 Directors Solicitor Mr Jonathan Stewart - Chairman Gilbert & Tobin Mr Ian Lusted – Chief Executive Officer Level 16, Brookfield Place Tower 2 Mr Graham Dowland – Chief Financial Officer 123 St Georges Terrace Mr Stephen Scudamore – Non-Executive Director Perth, Western Australia 6000 Mr Alan Watson – Non-Executive Director Company Secretary Stock Exchange Listing Ms Julie Foster The ordinary shares of Australis Oil & Gas Limited are listed on the Australian Securities Exchange (Ticker code: ATS) Registered and Principal Office Auditor Level 1 162 Grand Boulevard BDO Audit Pty Ltd Joondalup, Western Australia 6027 Level 9, Mia Yellagonga Tower 2, Telephone: +61 8 9220 8700 5 Spring Street Facsimile: +61 8 9220 8799 Perth, Western Australia 6000 Office in North America Website and Email Australis TMS Inc. www.australisoil.com 3 Allen Center [email protected] 333 Clay Street, Suite 3680 Houston, Texas 77002 Telephone: +1 (346) 229 2525 Share Registry Computershare Investor Services Pty Ltd Level 17, 221 St Georges Terrace Perth, Western Australia 6000 Telephone: +61 8 9323 2000 Facsimile: +61 8 9323 2033 ABN 34 609 262 937 Directors’ report 4 The Directors of Australis Oil & Gas Limited present their report on the consolidated entity consisting of Australis Oil & Gas Limited (“Company” or “Australis”) and the entities it controlled (“Consolidated Entity” or “Group”) for the half-year ended 30 June 2026. Directors The names of directors of the Company in office at any time during or since the end of the financial half-year ended 30 June 2026 are: Mr Jonathan Stewart Chairman Mr Ian Lusted Managing Director and Chief Executive Officer Mr Graham Dowland Finance Director and Chief Financial Officer Mr Stephen Scudamore Independent Non-Executive Director Mr Alan Watson Independent Non-Executive Director Each director held their office from 1 January 2026 until the date of this report. Results and review of operations The principal activity of the Group is oil and gas exploration, development and production. The Company operates one area of interest onshore being leases, wells and facilities in the Tuscaloosa Marine Shale (TMS) in the states of Louisiana and Mississippi in the USA. A summary of the activity of the project during the period is set out in the Operating Review below. All references to dollars in this report will be US$ unless stated otherwise. OPERATING REVIEW As announced at the end of 2025, Australis closed on two separate but strategically related transactions that together delivered on many of the key near term objectives of the Company. In combination the two transactions achieved the following:  secured a reputable and experienced US listed independent oil and gas company with financial capacity to deploy development capital in the TMS play (Development Partner);  successfully leveraged the inherent value in the Company’s undeveloped TMS acreage position by way of a ‘free carry program’ from the Development Partner to fund the Australis’s share of an early development program, rather than rely on shareholder equity or debt;  created an Area of Mutual Interest (AMI) with the Development Partner allowing Australis to participate in the growth of the existing acreage position; and  strengthened the Company’s balance sheet via the sale of 90% of its WI in existing TMS producing wells, enabling repayment in full of all the Macquarie Facility debt whilst maintaining a materially increased cash reserve. During the half year ended 30 June 2026 Australis, together with its/our Development Partner, began preparations for the Initial Test Well in the $46.25 million Carry Program. As part of the preparation a permit has been issued for the drilling of the Initial Test Well, the Willson 1H and, post the balance sheet date, Australis has received notification from the Development Partner to proceed with the drilling and completing of the Willson 1H in Q4 2026 with the planned spud date to be driven by rig availability. The permit application process has been initiated for a second Carried Well, designated the Mathieu 1H. In addition, leasing has commenced as part of the Development Partner’s carried $1 million Initial Leasing Program as well as within units that have been permitted or which are planning to be permitted. . In December 2025 Australis closed on its Financing Transaction with an affiliate of the EQV Group (EQV) to sell 90% of its working interest in its operated and non-operated producing well inventory for $16.9 million before customary closing adjustments. As a result of the transaction, at the end of 2025 all outstanding Macquarie Bank debt and interest was repaid and outstanding hedge swap contracts closed out. During the reporting period EQV was operator of Australis’ average ~10% WI in 31 wells within the Tuscaloosa Marine Shale (TMS) and Australis has a further average ~1% WI in 17 non-operated wells. As part of the Financing Transaction Australis was engaged by EQV to provide transition operator services during the first quarter of 2026 resulting in income of $138,000 during the reporting period. ABN 34 609 262 937 Directors’ report 5 A summary of the results and activities for the six months to 30 June 2026 are as follows.  During the six-month reporting period the Australis team worked with counterparts at the Development Partner across multiple disciplines to commence preparatory work for the permitting of the Initial Test Well and other Carry Wells and detailed planning and completion designs. The permit for the Willson 1H has been issued and work has commenced on securing a spud date for Q4 2026. Australis will be the designated operator of the Willson 1H and has retained the operational staffing levels required to meet this obligation together with the necessary contracted technical expertise.  Total sales volumes (WI) during the period were approximately 9,200 bbls (1H 2025: 110,000 bbls).  Production from the wells was in line with expectations, allowing for natural decline and outages due to weather-related events.  Sales revenue (WI) of $0.5 million reflected gross sales revenue of $0.8 million less oil price hedge collar contract settlement loss ($0.1 million) and a non-recurring ($0.2 million) prior period adjustment (activity period 2014 to 2025) as a result of ownership changes identified as two wells reached payout.  Achieved realised pricing averaged $85/bbl (excluding realised hedge losses and prior period adjustment), which was 20% higher than for the first half of 2025. An oil price hedge loss of $0.1 million was recognised in 1H 2026 (1H 2025: $1,000 gain) on the close out of the remaining zero collar hedges retained following the Financing Transaction.  Four workovers were completed during the reporting period within budget.  Field netback of ($0.1 million) substantially as a result of the prior period adjustment of ($0.2 million) from sales revenue.  Capital expenditure in the period of $21,000 related to extension of specified leases as agreed with our Development Partner.  In January 2026, Australis released its independently assessed net reserves and resources estimates1 for the TMS as at 31 December 2025 having adopted a conservative approach to estimating its oil and gas reserves and resources by not assuming any future development plan. Future production from existing wells was assessed in a manner consistent with previous years and whilst a Development Partner has been introduced no development plan had been approved at 31 December 2025 and therefore the Board determined it would, as it has in previous years, not be appropriateSyntax Error: Unknown form type to propose a development plan as part of the YE2025 reserves evaluation. The 31 December 2025 reserve and resource estimate consists of a proved, probable and possible developed reserve estimate only (i.e. for the existing wells only) and no reserve estimates have been generated for undeveloped acreage. A contingent resource estimate is provided for the undeveloped acreage and, as in previous years, the mid case 2C contingent resource is subject to a qualifying development plan to transition volumes to an appropriate reserve category of proved, probable and possible. The Proved Developed Producing reserves net (after royalties) to Australis totaled 165 thousand barrels and the 2P + 2C net reserves and resources (mid case) totaled 62 million barrels1,2 on a pre farmout basis. ABN 34 609 262 937 Directors’ report 6 FINANCIAL AND CAPITAL MANAGEMENT During the period, the Consolidated Entity made a net loss after tax of $2.6 million (1H 25: Loss $1.9 million). As at 30 June 2026, Australis has cash and cash equivalents of $11.2 million (31 December 2025: $14.2 million). The operating results for Australis for the period ending 30 June 2026 is as follows: Summary Financial Results 30 June 2026 US$ millions 30 June 2025 US$ millions Revenue (including hedging gain/(loss))(1) $0.5 $7.7 Royalties ($0.1) ($1.5) Direct operating costs & taxes ($0.5) ($3.7) Field Netback ($0.1) $2.5 Other income 0.1 - Corporate costs ($2.5) ($1.6) Share based payments ($0.1) ($0.2) Adjusted EBITDA ($2.6) $0.7 Net interest expense $0.2 ($0.4) Depreciation and depletion ($0.2) ($2.2) (Loss) before taxation ($2.6) ($1.9) (1) Including a hedge loss of ($0.1) and non-recurring prior period adjustment of ($0.2) for the activity period 2014 to 2025 as a result of ownership changes identified as two wells reached payout. Significant changes in the state of affairs The significant changes in the state of affairs of the Consolidated Entity during the financial period and to the date of this report are set out in the review of operations above and the events after the reporting date below. Dividends In respect of the period ended 30 June 2026, no dividends have been paid or declared and the Directors do not recommend the payment of a dividend in respect of the financial period. Events after the reporting date No events have occurred since 30 June 2026 that would materially affect the operations of the Group, the results of the Group or the state of affairs of the Group not otherwise disclosed in the Group’s Financial Statements. Rounding off of amounts The Directors’ Report and Financial Statements are rounded off to the nearest thousand dollars as permitted under ASIC Corporations Instrument 2026/183, unless otherwise indicated. Auditor’s independence declaration The auditor’s independence declaration is included on page 10 of the half-year report. The Director’s Report is signed in accordance with a resolution of Directors made pursuant to section 306(3) of the Corporations Act. Jonathan Stewart 19 August 2026 ABN 34 609 262 937 Directors’ report 7 FOOTNOTES 1. Estimates from the independent Ryder Scott report, effective 31 December 2025 and dated 29 January 2026, which was initially disclosed in the announcement titled “Quarterly Activities and Annual Reserve Report’ issued on 30 January 2026 The report was prepared in accordance with the definitions and disclosure guidelines contained in the Society of Petroleum Engineers (SPE), World Petroleum Council (WPC), American Association of Petroleum Geologists (AAPG), and Society of Petroleum Evaluation Engineers (SPEE) Petroleum Resources Management (SPE-PRMS) as revised in June 2018. Ryder Scott generated their independent reserve and contingent resource estimates using deterministic methods. The achieved price and NPV(10) values quoted are for the project only, they do not include any impact from any oil price hedges that Australis had entered into at that time. Australis is not aware of any new information or data that materially affects the information included in the referenced announcement and all the material assumptions and technical parameters underpinning the estimates in the original announcement continue to apply and have not materially changed. 2. The figures quoted is the rounded arithmetic sum of the 2P reserve and 2C resource estimate as reported in the Ryder Scott reserve report dated 29 January 2026. That report included the following reserve and resource estimates of oil. The 1P, 2P and 3P figures provided are the arithmetic summation by category and are referenced to the individual well oil metering at each producing well location. The 1C, 2C and 3C figures provided are the arithmetic summation by category. Net Oil Reserves (Mbbls) Contingent Oil Resources (Mbbls) 1P 128 1C 19,709 2P 165 2C 62,156 3P 213 3C 112,498 ABN 34 609 262 937 Directors’ report 8 Non-IFRS Financial Measures References are made within this report to certain financial measures that do not have a standardised meaning prescribed by International Financial Reporting Standards (IFRS). Such measures are neither required by, nor calculated in accordance with IFRS, and therefore are considered Non–IFRS financial measures. Field Netback and Adjusted EBITDA, as defined within the Glossary, are Non-IFRS financial measures commonly used in the oil and gas industry or financial measures that are relevant to Australis. Non-IFRS financial measures used by the Company may not be comparable with the calculation of similar measures by other companies. The following table reconciles net loss after tax to earnings excluding non-cash items. Half year ended 30 June 2026 30 June 2025 $’000 $’000 Net (loss) after tax (2,593) (1,885) Adjustments: Depletion 78 1,453 Depreciation 117 703 Share based payments 70 211 Unrealised foreign exchange (gain)/loss 14 (2) Inventory adjustment 14 3 Earnings excluding non-cash items (2,300) 483 ABN 34 609 262 937 Directors’ report 9 GLOSSARY Term Definition bbl(s) Barrel(s) of oil Adjusted EBITDA represents net income /(loss) for the period before any income tax expense or benefit, finance costs, depletion, depreciation, expired lease write off, and impairment. Field Netback Oil and gas sales net of royalties, production and state taxes, inventory movements, hedging gains or losses, field based production expenses but excludes depletion and depreciation LLS Louisiana Light Sweet Oil Benchmark Price WTI West Texas Intermediate Oil Benchmark Price 1P Proved Developed Reserves (PDP + PDNP) 2P Probable Reserves 3P Possible Reserves C Contingent Resources (1C/2C/3C equivalent to low/most likely/high) AMI Area of Mutual Interest within the TMS Core where Australis has the right to participate with Development Partner at a 20% working interest in any new leases taken Carry Program The carried TMS development work program contemplated by the Development Transaction, pursuant to which Development Partner will carry Australis for a 20% working interest Development Partner A US listed independent oil and gas company with a multi-billion dollar enterprise value and active onshore development and exploration operations in multiple unconventional US basins EQV An affiliate of the EQV Group Financing Transaction A Transaction closed on 30 December 2025 whereby Australis sold 90% of its working interest in producing TMS wells for $16.9 million, subject to customary closing adjustments Initial Leasing Program $1 million lease program within the AMI under the Development Transaction where Australis is carried by the Development Partner for a 20% working interest Initial Test Well The first carried well to be drilled under the Development Transaction Net or NRI Company beneficial interest after royalties or burdens Net Acres Working Interest before deduction of royalties or burdens NPV(10) Net Present Value (@ discount rate) PDNP Proved Developed Not Producing Reserves PDP Proved Developed Producing Reserves Royalty Interest in a leasehold area providing the holder with the right to receive a share of production associated with the leasehold area TMS Tuscaloosa Marine Shale WI Company beneficial interest before royalties ABN 34 609 262 937 Auditors’ independence declaration 10 ABN 34 609 262 937 Independent review report 11 ABN 34 609 262 937 Independent review report 12 ABN 34 609 262 937 Directors’ declaration 13 In the Directors’ opinion: (a) the financial statements and accompanying notes set out on pages 14 to 27, are in accordance with the Corporations Act 2001, including: (i) complying with Accounting Standards and the Corporations Regulations 2001 and other mandatory professional reporting requirements; and (ii) giving a true and fair view of the Consolidated Entity’s financial position as at 30 June 2026 and of its performance for the half-year ended on that date. (b) there are reasonable grounds to believe that the Consolidated Entity will be able to pay its debts as and when they become due and payable. Signed in accordance with a resolution of the Directors. Jonathan Stewart Chairman Perth, Western Australia 19 August 2026 ABN 34 609 262 937 Consolidated Statement of Profit or Loss and Other Comprehensive Income For the half-year ended 30 June 2026 14 Half-year ended 30 June 2026 Half-year ended 30 June 2025 Notes US$’000 US$’000 Revenue 2.2 508 7,720 Cost of sales 2.3 (797) (7,283) Gross (loss) / profit (289) 437 Other income 2.2 138 - Other expenses 2.4 (2,646) (1,926) (Loss) from operating activities (2,797) (1,489) Net finance income/(e