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February 26 FY26 half year results 5 February 2026 For personal use only
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Disclaimer This presentation contains forward-looking statements, including statements of current intention, opinion and predictions regarding the Company’s present and future operations, possible future events and future financial prospects, and new energy initiatives and emissions intensity reduction targets. While these statements reflect expectations at the date of this presentation, they are, by their nature, not certain and are susceptible to change. Beach makes no representation, assurance or guarantee as to the accuracy or likelihood of fulfilling of such forward looking statements (whether expressed or implied), and except as required by applicable law or the ASX Listing Rules, disclaims any obligation or undertaking to publicly update such forward-looking statements. It should be noted that no universally accepted framework (legal, regulatory, or otherwise) currently exists in relation to ESG reporting. The inclusion or absence of information in Beach’s ESG statements should not be construed to represent any belief regarding the materiality or financial impact of that information. ESG statements may be based on expectations and assumptions that are necessarily uncertain and may be prone to error or subject to misinterpretation given the long timelines involved and the lack of an established single approach to identifying, measuring and reporting on many ESG matters. Furthermore, no assurance can be given that such a universally accepted measurement framework or consensus will develop over time. Although there are regulatory efforts to define such concepts, the legal and regulatory framework governing sustainability is still under development. Calculations and statistics included in ESG statements may be based on historical estimates, assumptions and projections as well as assumed technology changes and therefore subject to change. Beach’s ESG statements have not been externally assured or verified by independent third parties. Underlying EBITDAX (earnings before interest, tax, depreciation, amortisation, evaluation, exploration expenses and impairment adjustments), underlying EBITDA (earnings before interest, tax, depreciation, amortisation, evaluation and impairment adjustments), underlying EBIT (earnings before interest, tax, and impairment adjustments) and underlying profit are non-IFRS financial information provided to assist readers to better understand the financial performance of the underlying operating business. They have not been subject to audit or review by Beach’s external auditors. The information has been extracted from the audited or reviewed financial statements. Free cash flow is defined as net cash flow before debt repayments, dividends, transaction adjustments and foreign exchange movements. Pre-growth free cash flow defined as operating cash flows, less investing cash flows excluding acquisitions, divestments and major growth capital expenditure, less lease liability payments. It has not been subject to audit or review by Beach’s external auditors. The information has been extracted from the audited or reviewed financial statements. The Board will have the discretion to adjust free cash flow for individually material items. All references to dollars, cents or $ in this presentation are to Australian currency, unless otherwise stated. References to “Beach” may be references to Beach Energy Limited or its applicable subsidiaries. References to planned activities in FY26 and beyond FY26 may be subject to finalisation of work programs, government approvals, joint venture approvals and board approvals. Due to rounding, figures and ratios may not reconcile to totals throughout the presentation. Assumptions Guidance is uncertain and subject to change. Production and capital expenditure guidance and other forecasts, projections, estimates and targets in this presentation are subject to change and have been estimated on the basis of the following economic assumptions: 1. Brent oil price of US$63.7 per barrel for FY26, US$61.8 per barrel for FY27 and US$65.3 per barrel for FY28, 2. AUD/USD exchange rate of 0.66 for FY26, 0.67 for FY27 and 0.66 for FY28, 3. various other economic and corporate assumptions, 4. assumptions regarding drilling results, and 5. expected future development, appraisal and exploration projects being delivered in accordance with their current expected project schedules. These future development, appraisal and exploration projects are subject to approvals such as government approvals, joint venture approvals and Board approvals. Beach expresses no view as to whether all required approvals will be obtained in accordance with current project schedules. Reserves disclosure Reserves and resources estimates are prepared in accordance with the 2018 update to the Petroleum Resources Management System (SPE-PRMS). Storage resources are prepared in accordance with the 2017 CO2 Storage Resources Management System (SPE-SRMS). Both systems are sponsored by the Society of Petroleum Engineers (SPE), World Petroleum Council, American Association of Petroleum Geologists and Society of Petroleum Evaluation Engineers, Society of Exploration Geophysicists, Society of Petrophysicists and Well Log Analysts and the European Association of Geoscientists & Engineers. The statement presents Beach’s net economic interest estimated at 30 June 2025 using a combination of probabilistic and deterministic methods. Each category is aggregated by arithmetic summation. Note that the aggregated 1P category may be a conservative estimate due to the portfolio effects of arithmetic summation. Reserves are stated net of fuel, flare and vent at reference points generally defined by the custody transfer point of each product. Conversion factors used to evaluate oil equivalent quantities are oil - 1 boe per bbl, condensate - 0.935 boe per bbl, sales gas - 171,940 boe per PJ, LPG - 8.458 boe per tonne, and LNG - 9.531 boe per tonne. Reserves are stated net of fuel, flare and vent at reference points defined by the custody transfer point of each product. The estimates are based on, and fairly represent, information and supporting documentation prepared by, or under the supervision of, Qualified Petroleum Reserves and Resources Evaluators (QPRRE) employed by Beach. The QPRRE is Mark Sales who is a member of SPE. Authorisation This presentation has been authorised for release by the Beach Energy Board of Directors. Compliance statements 2 For personal use only
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Milestones 3 >15 PJ sold into spot and short-term markets Early Western Flank drilling success $300 million term loan secured Equinox Phase 1 complete >1.5 Mt of CO2e safely injected to date Moomba CCS issued >300,000 (net) ACCUs Delivery of major projects with outstanding safety and environmental performance Waitsia Gas Plant ramp up underway >12-months recordable injury free Four LNG cargoes delivering $233m 97% of flood-impacted production restored For personal use only
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9.5 MMboe 7% PRODUCTION TOTAL REVENUE $1 billion 0% UNDERLYING EBITDA $558 million 5% Continued performance across key metrics, strengthened liquidity to pursue growth H1 FY26 headline results1 4 1. Relative to H1 FY25 2. Pre-growth free cash flow defined as operating cash flows less investing cash flows excluding acquisitions, divestments and major growth capital expenditure, less lease liability payments 12.7 MMboe 3% SALES VOLUMES $11.8/GJ 13% AVERAGE REALISED GAS PRICE PRE-GROWTH FREE CASH FLOW2 $225 million 48% FULLY FRANKED INTERIM DIVIDEND DECLARED 1.0 cps 67% $925 million 47% TOTAL LIQUIDITY For personal use only
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5 Health, safety and environment Achieving exceptional HSE outcomes 2 2 1 0 12 4 8 4.4 2.4 3.4 0.8 0.0 0 1 2 3 4 5 0 4 8 12 16 FY22 FY23 FY24 FY25 H1 FY26 Total Recordable Injuries Employees Contractors TRIFR 2 1 1 0 1 2 FY22 FY23 FY24 FY25 H1 FY26 Process Safety Tier 1 Tier 2 1 Personal safety performance Process safety performance Key highlights ▪ Outstanding HSE performance across all operations o 12 months recordable injury free across Beach operations achieved in December o No Process Safety Tier 1 or 2 events ▪ Safe commencement of the Cooper Basin and Equinox rig campaigns 1. Total Recordable Injury Frequency Rate is the frequency of recordable injuries for each one million hours worked (12-month rolling) For personal use only
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Waitsia Gas Plant 6 Operator Waitsia Gas Plant production ramp profile West Coast Waitsia Gas Plant online and ramp-up underway • Waitsia Stage 2 successfully transitioned from project construction and commissioning activities to production operations • Achieved peak production rate of 165 TJ/day1 • Commissioning of third and fourth compressors in Q3 FY26 targeted, production rates expected to ramp up towards nameplate capacity (250 TJ/day) • Critical infrastructure for the West Australian market Dec-25 Jan-26 Feb-26 Mar-26 TJ/day Production Operator's Forecast Ramp Profile 6 Nameplate capacity 250TJ/day 2 1. Peak production rate at Waitsia Gas Plant achieved in January 2026, after half year end 2. Mitsui Operator forecast as per WA Gas Bulletin Board Capacity Outlook as at 2 February 2026 For personal use only
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100 200 300 400 2026 2027 2028 2029 2030 2031 2032 2033 2034 Supply Demand “Gas underpins a wide range of economic activity in Australia and globally, with secure gas supplies being a core component of energy security” Gas Market Review Report Department of Climate Change, Energy, the Environment and Water, December 2025 Delivering and investing in material East Coast gas supply Leveraging hydrocarbon assets to support future East Coast energy requirements East Coast gas outlook (PJ)1 7 1. AEMO 2025 Gas Statement of Opportunities (March 2025): Projected supply and demand in southern regions, Step Change scenario; supply includes LNG flow from northern regions 2. Beach gas supply from operated assets and non-operated equity interests relative to total demand from SA, VIC, NSW and QLD (non-LNG) Beach contribution ▪ >$2 billion of capital invested over five years to discover and develop new gas supply ▪ 100% of East Coast gas production delivered to East Coast customers in H1 FY26 (18% of total demand2) ▪ Continued investment with multiple ongoing campaigns ▪ Strategy to deliver gas for power generation, manufacturing and emerging demand, including data centres and AI Gas Market Review ▪ Beach supports a prospective domestic gas reservation policy to ensure supply adequacy ▪ Should prioritise domestic only gas producers delivering to Australian manufacturers and power generation, bolstering Australian jobs ▪ Must deliver sustainable, long-term solutions to enable investment certainty and new supply ▪ Focus on supply close to customers and infrastructure New demand growth expected from emerging industries For personal use only
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8 8 Nearshore • Progressing assessment of nearshore exploration opportunities • Final investment decision planned for H1 FY27 Onshore • Ongoing drilling activities in the Cooper Basin JV – Four rigs targeting ~100 wells per annum • Commence assessment of recently acquired Queensland acreage (~7,000 km2) East Coast Continued investment in East Coast gas supply Offshore Established infrastructure and operations • Existing production from onshore and offshore gas fields • Plant reliability >99% at all operated sites • Equinox Phase 2 planned for H2 FY26 – to include Thylacine West 1 intervention, Artisan 1 completion and La Bella 2 drill and completion • Final investment decision on Artisan and La Bella connections targeted in H2 FY26 For personal use only
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Oil appraisal and development campaign 9 East Coast Inventory refresh delivering quality drilling prospects • 12-well campaign commenced December 2025 • Fit for purpose onshore rig, with 20% reduction in man-hours compared to prior campaigns • 100% success from six wells drilled to date, with accelerated, low- cost connection program underway Oil exploration campaign • 10-well campaign to commence in late FY26 into FY27 • Extending exploration play horizons to unlock scale • Targeting to organically build 2P reserves and 2C resources and refresh exploration inventory for future campaigns 9 For personal use only
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Second half focus Focused activity across core East and West Coast hubs 10 Expand commercial marketing with industrial sector and gas-power generators Ongoing Cooper Basin JV drilling and progress Moomba Central Optimisation Thylacine West intervention, La Bella 2 drill/completion and Artisan completion Waitsia Gas Plant production ramp up Complete planned offshore abandonment scope Complete Western Flank 12-well oil development and appraisal campaign; commence 10-well exploration campaign For personal use only
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Financial results FY26 half year results For personal use only
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$ million (unless otherwise indicated) H1 FY25 H1 FY26 Change Production (MMboe) 10.2 9.5 (7%) Sales volumes (MMboe) 12.3 12.7 3% Sales revenue 990 982 (1%) Average realised oil price ($ per bbl) 125 110 (12%) Average realised gas price ($ per GJ) 10.5 11.8 13% Underlying EBITDA1 587 558 (5%) Underlying EBITDA1 margin (%) 59% 57% (2%) Underlying NPAT1 237 219 (8%) Statutory NPAT 222 150 (32%) Operating cash flow 659 442 (33%) Free cash flow2 239 61 (75%) Net debt3 389 445 14% 12 Headline financial metrics Results supported by LNG cargoes and strengthened gas prices 1. Underlying results in this presentation are categorised as non-IFRS financial information provided to assist readers to better understand the financial performance of the underlying operating business. They have not been subject to audit or review by Beach’s external auditor 2. Free cash flow defined as operating cash flows less investing cash flows excluding acquisitions, divestments, less lease liability payments 3. Net debt / (cash) defined as interest bearing liabilities less cash and cash equivalents 50% 24% 14% 13% Gas liquids LNG $982 million Gas Oil H1 FY26 sales revenue For personal use only
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(1) (4) (44) 237 22 7 2 219 H1 FY25 Other Tax DD&A Cash costs Revenue Inventory movements H1 FY26 1. Underlying results in this presentation are categorised as non-IFRS financial information provided to assist readers to better understand the financial performance of the underlying operating business. They have not been subject to audit or review by Beach’s external auditors, 2. Cash costs include field operating costs, tariffs and tolls, royalties, carbon costs and third-party purchases 3. Includes movements to other income ($10 million), net financing costs ($3 million) and other expenses excluding corporate depreciation ($9 million) 2 Underlying NPAT of $219 million down 8%: ▪ Higher cost of sales, including third party purchases and non-cash inventory movements to facilitate Waitsia LNG cargoes ▪ Sales revenues $1bn, <1% down, reflecting softer oil and liquids pricing, offset by strengthened realised gas prices and two additional LNG cargoes Partially offset by: ▪ Lower field operating costs, reflecting strict cost discipline across Beach operated assets ▪ Increase to other income reflects non-cash revaluation of overlift liabilities and foreign exchange gains. 3 $ million Underlying NPAT movements1 Commercial strategy and cost discipline delivered earnings of $219 million 13 For personal use only
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Cash reserves movements Positive cash generation through a capital-intensive period (212) (165) (137) (4) (1) 172 442 140 235 30-Jun-25 Operating Debt Sustaining capex Growth capex Dividends Leases Other 31-Dec-25 $ million ▪ Operating cash flow of $442 million o Net operating receipts of $692 million o Income tax payments of $126 million o Restoration payments of $107 million ▪ $377 million capital expenditure payments o Growth expenditure of $165 million for major project delivery • Record fully franked FY25 final dividend of 6.0 cents per share paid in September 2025 ▪ Lease liability payments of $4 million per AASB 16 – Leases 14 For personal use only
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Strong financial position Strengthened liquidity position to support growth activities (540) (680) 172 235 480 690 30-Jun-25 31-Dec-25 Available Liquidity ($ million) Undrawn debt Cash reserves Drawn debt 925 652 ▪ Successful refinance of 2025 and 2026 maturities at strong terms ▪ $300m Term Loan secured on competitive terms with strong lender support ▪ $925 million available liquidity at 31 December 2025 o 12% net gearing1 ▪ Fully franked interim dividend declared of 1.0 cent per share 1. Net gearing defined as Net Debt / (Net Debt + Equity) 15 For personal use only
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February 26 Outlook FY26 half year results For personal use only
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FY26 guidance Production and capital expenditure guidance unchanged 8% 82% 10% Oil Gas Gas liquids 1. Growth capital expenditure: Spend on major infrastructure projects and development projects and offshore drilling. FY26 includes completion of Waitsia Stage 2, the Equinox rig campaign and Cooper Basin exploration activities 2. Waitsia Gas Plant nameplate capacity of 250 TJ/day 3. H1 FY26 one-off expense items include $33 million incurred in relation to unavoidable costs for transportation, processing and sale of LNG prior to completion of the Waitsia Stage 2 project and $8 million for Cooper Basin flood remediation costs 4. FY26 largely reflects Equinox rig campaign abandonment expenditure and minor regular onshore abandonment activities Up to 55% Up to 45% Sustaining Growth1 FY26 outlook Production Capital expenditure Cooper Basin JV Flood recovery largely complete at end of H1 FY26 Four rigs targeting ~80 wells; Moomba Central Optimisation Western Flank Flood recovery largely complete, remaining impacted production expected to be recovered through Q3 FY26. Expected to commence connections from current campaign during H2 FY26 12-well oil development and appraisal campaign in H2 FY26; commence 10- well oil exploration campaign in late FY26 Otway Basin Production down by up to 20% from field decline, planned maintenance and commercial offtake assumptions Equinox rig campaign drilling and completions Perth Basin Waitsia Gas Plant; 3-4 month ramp-up to 90% plant utilisation2 for FY26 Final stages of Waitsia Gas Plant commissioning; geological studies Includes Equinox rig campaign ($250-300 million) 17 Other items H1 FY26 FY26 One-off expense items3 $41 million $41 million D&A (excludes corporate D&A) $222 million $450 - 500 million Abandonment expenditure4 $98 million $200 - 250 million Production: 19.7 – 22.0 MMboe (no change) Capital expenditure: $675 – 775 million (no change) For personal use only
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Wrap-up and Q&A FY26 half year results For personal use only
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19 Beach value proposition To become Australia’s leading domestic energy company with a clear East and West Coast gas focus Owner’s mindset✓ Operational excellence✓ Growing domestic gas supply✓ Total shareholder return focus✓ Significant contributor to the economy1 ✓ Strong Balance Sheet✓ Perth Basin Waitsia Beach 50% (non-operated) 250 TJ/day Waitsia Gas Plant 30 TJ/day Xyris Gas Plant Beharra Springs Beach 50% (operated) 25 TJ/day Beharra Springs Gas Plant Otway Basin Beach 60% (operated) 205 TJ/day Otway Gas Plant Gas storage potential Gas peaking power potential Cooper Basin Cooper Basin JV Beach various interests (non-operated) 310 TJ/day Moomba Gas Plant 1.7 Mtpa CO2e injection capacity Western Flank Beach 75-100% (operated) 22 TJ/day Middleton Gas Plant Oil infrastructure SA Otway Basin Beach 70-100% (operated) Katnook Gas Plant Bass Basin Beach 100% (operated) Lang Lang Gas Plant Taranaki Basin Beach 50% (operated) Kupe Gas Plant 1. In addition to significant capital investment, Beach is supporting domestic energy security, creating jobs for local communities and has contributed approximately $2.3 billion in taxes and royalties to state and federal governments over the five years to end-FY25 For personal use only
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Appendix FY26 half year results For personal use only
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Reconciliation of EBITDA and NPAT ($ million) H1 FY25 H1 FY26 Change Underlying EBITDA 587 558 (5%) Tariffs and tolls related to unutilised NWS capacity (21) (33) Exploration write-off - (61) Insurance recoveries 2 6 Legal costs related to shareholder class action (2) (2) Cooper Basin flood costs - (8) EBITDA 566 459 (19%) Depreciation and amortisation (228) (226) Finance expenses (20) (17) Tax (96) (66) Statutory NPAT 222 150 (32%) Tariffs and tolls related to unutilised NWS capacity 21 33 Exploration write-off - 61 Insurance recoveries (2) (6) Legal costs related to shareholder class action 2 2 Cooper Basin flood costs - 8 Tax impact of the above (6) (29) Underlying NPAT 237 219 (8%) 21 For personal use only
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Segment information SA WA Victoria NZ Corporate Total ($ million) H1 FY25 H1 FY26 H1 FY25 H1 FY26 H1 FY25 H1 FY26 H1 FY25 H1 FY26 H1 FY25 H1 FY26 H1 FY25 H1 FY26 Production (MMboe) 4.5 3.8 0.8 0.8 4.1 4.2 0.8 0.8 10.2 9.5 Sales volumes (MMboe) 5.4 4.3 2.0 3.5 4.1 4.1 0.9 0.7 12.3 12.7 Sales revenue 479 374 157 259 298 298 55 51 990 982 Total revenue 525 420 157 259 307 310 55 51 1,044 1,040 Field operating costs (75) (68) (5) (6) (36) (32) (11) (11) (127) (117) Tariffs, tolls and other (80) (84) (58) (70) (12) (13) (0) (0) (149) (168) Carbon costs - - - - - - (2) (0) (1) (0) Royalties (39) (29) - (2) (9) (9) (7) (7) (55) (47) D&A (119) (95) (7) (8) (88) (109) (9) (10) (223) (222) Third party purchases (88) (64) (15) (61) - - - - (103) (125) Change in inventories 3 9 (22) (75) (0) (0) (3) 0 (22) (66) Gross profit 127 89 51 36 161 147 23 23 363 294 Other income - 0 - 5 1 9 - - 3 4 4 19 Other expenses (8) (4) (2) - (0) (61) (7) (3) (12) (11) (29) (80) Net financing costs (20) (18) (20) (17) Profit / (loss) before tax 120 85 50 42 162 94 16 19 (29) (24) 318 216 Income tax benefit / (expense) 96 66 96 66 Net profit / (loss) after tax 222 150 22 For personal use only
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Perth Basin Privileged infrastructure to service West Coast domestic gas and global LNG markets 23 ▪ Interest: 50% interest and operator of EP320, L11 and L22 (Mitsui 50%); 50% interest in L1 and L2 (Mitsui 50% and operator) ▪ Assets: Waitsia Gas Plant (250 TJ/day capacity); Beharra Springs Gas Plant (25 TJ/day capacity); Xyris Gas Plant (30 TJ/day capacity); Beharra Springs and Waitsia gas fields; Redback Deep and Tarantula Deep gas discoveries ▪ H1 FY26 production: 0.8 MMboe ▪ First gas from the Waitsia Gas Plant delivered, peak rate to date of 165 TJ/day achieved ▪ $233 million revenue from four Waitsia LNG cargoes lifted ▪ Seven years recordable injury free at Beharra Springs ▪ 99% reliability at the Beharra Springs and Xyris Gas Plants ▪ Waitsia Gas Plant ramp up towards nameplate capacity ▪ Assessment of development options for existing discoveries ▪ Maturation of exploration opportunities to drill ready status Asset overview: H1 FY26 milestones: H2 FY26 focus: For personal use only
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Otway Basin Delivering new gas supply for the East Coast market ▪ Interest: 60% interest and operator (O.G. Energy 40%) ▪ Assets: Otway Gas Plant (205 TJ/day capacity); Black Watch, Enterprise, Geographe, Halladale, Speculant and Thylacine gas fields; Artisan and La Bella gas discoveries ▪ H1 FY26 production: 3.3 MMboe ▪ Equinox Phase 1 activity completed; Geographe 1 and Thylacine 1 plugged and abandoned, Hercules 1 exploration well drilled ▪ Two years recordable injury free at the Otway Gas Plant ▪ 99% reliability at the Otway Gas Plant 1. For gas supply from the Geographe, Thylacine, Halladale, Black Watch and Speculant fields 24 Asset overview: H1 FY26 milestones: ▪ Thylacine West well intervention ▪ Drilling and completion of the La Bella development well; completion of the Artisan discovery ▪ Progress assessment of nearshore drilling and development opportunities ▪ Commence three-yearly price review process for the Otway Basin GSA1 H2 FY26 focus: For personal use only
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Cooper Basin JV Delivering critical gas to the East Coast gas market 1. Beach owns non-operated interest in the South Australian Cooper Basin joint ventures (collectively 33.40% in SA Unit and 27.68% in Patchawarra East), the South West Queensland joint ventures (various interests of 30% to 52.5%) and ATP 299 (Tintaburra) (Beach 40%) 25 ▪ Interest: Various non-operated interests (Santos operator)1 ▪ Assets: Moomba Gas Plant (310 TJ/day capacity); Moomba CCS (up to 1.7 Mtpa CO2 injection capacity); ~200 producing oil and gas fields ▪ H1 FY26 production: 3.0 MMboe Asset overview: H1 FY26 milestones: ▪ Participation in 44 wells with an overall success rate of 84% ▪ Oil discovery at Kwaremont, gas discoveries at Daku and Purraroo ▪ Moomba CCS safely injected 550 kt CO2e, now >1.5 Mt CO2e stored to date ▪ Achieved Clean Energy Regulator performance requirements, Beach issued >300,000 ACCUs H2 FY26 focus: ▪ Support the operator to restore production at remaining flood-impacted wells ▪ Ongoing exploration, appraisal and development drilling (>30 wells scheduled in H2 FY26) ▪ Ongoing injection and storage of produced reservoir CO2 ▪ Progress Moomba Central Optimisation program ▪ Commence assessment of recently acquired Queensland acreage (~7,000 km2) For personal use only
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Western Flank Exploration drilling to follow current appraisal and development campaign 26 ▪ Interest: 100% interest and operator of PEL 91, PEL 104/111 and PEL 106; 75% interest and operator of PEL 92 (Amplitude Energy 25%) ▪ Assets: Middleton Gas Plant (22 TJ/day capacity); 29 producing oil fields and 10 producing gas fields ▪ H1 FY26 production: 0.8 MMboe Asset overview: H1 FY26 milestones: ▪ Flood recovery efforts restored road access and production from majority of flood-impacted wells ▪ Planning and preparation for FY26 and FY27 drilling campaigns ▪ Appraisal and development campaign commenced, three Callawonga wells cased and suspended ▪ Two years recordable injury free H2 FY26 focus: ▪ Connect successful Callawonga development wells ▪ Complete 12-well oil appraisal and development drilling campaign ▪ Commence 10-well oil exploration campaign ▪ Ongoing optimisation initiatives for sustainable cost savings For personal use only
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Bass Basin Taranaki Basin Interests: 100% interest and operator of T/L1, T/L5, T/RL4, T/RL5 and G-17-AP Assets: Lang Lang Gas Plant (67 TJ/day capacity); Yolla gas field H1 FY26 production: 0.9 MMboe Interest: 50% interest and operator (Genesis Energy 46%, Echelon Taranaki Limited 4%) Assets: Kupe Gas Plant (77 TJ/day capacity); Kupe gas field H1 FY26 production: 0.8 MMboe ▪ Safety takes precedence ▪ Small, focused operational teams ▪ Target self-sustaining / self-funding operations ▪ Compliant with strict operating principles ▪ Selective capital investment only 27 Non-core asset operating philosophy: For personal use only
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BEACH ENERGY LIMITED Level 8, 80 Flinders Street Adelaide SA 5000 Australia T +61 8 8338 2833 F +61 8 8338 2336 beachenergy.com.au INVESTOR RELATIONS Adam Stokes, Acting Head of Investor Relations T +61 8 8338 2833 For personal use only