Interim report
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Serica Energy plc('Serica' or 'the Company') Results for the six months ended 30 June 2026 London, 6 August 2026 - Serica Energy plc (AIM: SQZ), a British independent upstream oil and gas company with operations in the UK NorthSea, today announces its unaudited financial results for the six months ended 30 June 2026. The results are included below and copies are availableat www.serica-energy.com and www.sedar.com. Chris Cox, Serica's CEO, stated:"Serica delivered a strong first half, with robust production, material free cash flow and a significantly strengthened balance sheet. The operationalwork completed last year is now translating into much improved asset performance, most notably at Triton, and the addition of production fromnew assets has provided a further boost. Together with a supportive commodity price environment, this performance generated $184 million of freecash flow and enabled Serica to move from net debt at year-end 2025 to a net cash position at 30 June 2026. We have taken advantage of attractive market conditions and successfully completed both the issue of a new five-year Nordic Bond and refinancedour RBL facilities with a new six-year maturity $750 million facility. This gives Serica substantial liquidity and flexibility as we enter the nextphase of organic investment and portfolio growth. We expect to shortly confirm contracting of a rig to deliver our high-impact and rapid returnorganic growth projects in the UK North Sea, and continue to seek further opportunities to deliver shareholder value via M&A both in the UK andinternationally. A long-standing objective is to establish a significant international business to complement our position on the UKCS. The recommendedacquisition of Pharos Energy represents the first step in delivering that strategy, and the deal, should it complete, is set to deliver value accretive,materially cash-generative diversification and act as an ideal platform for further international growth." Results summary ($ million unless stated) H1 2026 H1 2025 FY 2025 Average realised Brent oil price ($/bbl)1 93 70 67 Average realised gas price (pence per therm)1 101 96 84 Production (boepd) 44,700 24,700 27,600Revenue 677 305 601Operating costs 239 156 367 EBITDAX2 301 118 210 Cash Tax received/(paid) 9 71 63 Post-tax CFFO2 280 173 243 Capital expenditure2 81 138 249 Free cash flow2 184 26 (24) Cash and restricted cash 326 174 31Total debt (300) (231) (231) Net cash / (net debt)2 26 (57) (200) Dividend declared (pence per share) 6 6 10 1 Pre-hedging, with hedging in the period resulting in actual average portfolio sales oil and gas prices of $73/bbl and 97p/therm respectively2 See non-IFRS measures HighlightsSignificant production growth driven by improved uptime and new West of Shetland contribution· Production increased to 44,700 boepd net to Serica in H1 2026 (H1 2025: 24,700 boepd), in line with guidance, a material increase fromthe prior year due to higher portfolio uptime and the addition of production from newly acquired assets West of Shetland- Production in Q2 averaged 50,200 boepd, underpinned by a step-change in Triton performance, where production contributed 20,300boepd with asset uptime of over 95% Material free cash flow drives move to net cash position · Serica is robustly positioned to take advantage of opportunities to create material shareholder value, with cash of $326 million as of 30June 2026 (31 December 2025: $31 million), a material increase since year end 2025 due to robust production, higher commodity prices,and the receipt of $56 million upon completion of the acquisition of assets West of Shetland from TotalEnergies· Net cash of $26 million as of 30 June 2026, following completion of $300 million five-year Nordic bond in May· Completion in July of six-year Reserves Based Lending ('RBL') facilities totalling $750 million supporting a robust liquidity position of$784 million as of 30 June 2026 pro forma for the new RBL borrowing base, providing substantial capacity to support the Company's UKinvestment programme, future decommissioning security requirements and disciplined M&A· Capital expenditure on a cash basis of $81 million in H1, of which $50 million was spent on the Bruce Hub· Interim dividend of 6p declared today (2025 interim dividend: 6p), reflecting the Board's confidence in Serica's cash generation andfinancial position- The interim dividend is payable on 19 November 2026 to shareholders registered on 23 October 2026, with an ex-dividend date of 22October 2026 Rig set to be leased ahead of high-impact organic growth programme
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· As detailed at the Capital Markets Day on 2 June, Serica has a portfolio of short-cycle projects with the potential to add 30,000 boepd ofincremental production, supporting annual average production of over 50,000 boepd into the next decade. The programme is expected todeliver average rates of return above 40%, reinforcing the capital efficiency of Serica's organic growth portfolio· Serica expects to sign a rig contract in the coming weeks for a drilling programme estimated at around 400 days duration, with an option toextend, giving the potential to drill up to six wells across the Company's expanded portfolio· Drilling is expected to begin with the Bruce SCE and SCW wells in Q3 2027, with the potential for first production 12 months from thestart of drilling Disciplined M&A adds scale, diversification and cash-generative growth· The acquisition of the 40% interest in the Greater Laggan Area from TotalEnergies completed on 26 March, adding a new operatedproduction and development hub in the high-potential West of Shetland basin· Post period end, Serica announced the recommended acquisition of Pharos Energy, completion of which would provide a first step in ourlong-standing strategic objective of adding international expansion, boosting our reserves, resources and adding cash-generativeproduction, presenting a platform from which to grow· Serica continues to rigorously evaluate a pipeline of M&A opportunities, both in the UK North Sea and other areas in which the Companycan successfully deliver its strategy Outlook and guidance· Serica remains on track to deliver production rates of c.65,000 boepd following completion of the Spirit Energy transaction· The acquisition of assets from Spirit Energy is now set to complete on 1 October 2026, resulting in revised production guidance for 2026of above 40,000 boepd (previously: significantly above 40,000 boepd)· Capital expenditure guidance of $175 to $195 million unchanged· Opex guidance of $380-400 million, excluding $65 million of Lancaster spend, unchanged· Post-tax CFFO guidance is impacted by the later completion of the Spirit Energy acquisition and is therefore revised to $450-475 million,consistent with current forward curve pricing· Work is progressing on the move from the AIM to the Main Market of the London Stock Exchange, remains on track to complete in 2026 RegulatoryThis announcement contains inside information for the purposes of Article 7 of the Market Abuse Regulation (EU) 596/2014 as it forms part of UK domestic lawby virtue of the European Union (Withdrawal) Act 2018 ('MAR'), and is disclosed in accordance with the company's obligations under Article 17 of MAR. The technical information contained in the announcement has been reviewed and approved by Carla Riddell, Chief Technical Officer at Serica Energy plc. Ms.Riddell (B.Sc. Geology from Durham University, M.Sc. Palynology from University of Sheffield) has over 25 years of experience in oil & gas exploration,development and production and is a Fellow of the Geological Society of London and Energy Institute. Enquiries: Serica Energy plc +44 (0)20 7487 7300 Martin Copeland (CFO) / Andrew Benbow (Head ofInvestor Relations) Peel Hunt (Nomad & Joint Broker) +44 (0)20 7418 8900Richard Crichton / David McKeown / Emily Bhasin Jefferies (Joint Broker) +44 (0)20 7029 8000Sam Barnett / Cameron Jones Vigo Consulting (PR Advisor) +44 (0)20 7390 0230Patrick d'Ancona serica@vigoconsulting.com Serica will host a live presentation on the Investor Meet Company platform today at 1000 BST. The presentation is open to all existing andpotential shareholders. Questions can be submitted at any time during the live presentation. Investors can sign up to Investor Meet Company forfree and add to meet Serica Energy plc via https://www.investormeetcompany.com/serica-energy-plc/register-investor. CHIEF EXECUTIVE OFFICER'S REVIEWThe first half of 2026 has been a positive one for Serica, with significant strategic delivery and a robust production performance that leaves us wellplaced to deliver on our growth plans and create material value for shareholders. The return of reliable performance at Triton demonstrates the underlying strength of the portfolio, with H1 production of almost 45,000 boepdproviding a stronger and more representative base for future growth. A lot of work has been put in across our assets, and especially at Triton, andwhile there is undoubtedly more to be done it is pleasing to see the work beginning to yield results. The resulting production increase, coupled with the relative strength of oil and gas prices in the period, saw a return to material cash generation.From a net debt position of $200 million at the end of 2025, we ended the period in a net cash position, as guided. Given the positive backdrop, wedecided to be proactive in our balance sheet management, firstly completing the issuance of a $300 million Nordic Bond and then post-period endsigning and completing new six-year RBL facilities totalling $750 million, with a further $750 million through an accordion facility. The end result of this is that, on a pro forma basis for the end of June, we have a liquidity position of $784 million and a portfolio that is materiallycash generative. This provides a strong financial platform from which to fund our UK North Sea investment programme while continuing to pursuedisciplined growth opportunities through M&A. We are in the final stages of discussions regarding the contracting of a rig from which to drill a high-impact multi-well programme across a rangeof our assets. Our rig inspection team has visited the rig and confirmed its suitability, and it is expected that our drilling programme will begin inQ3 2027 with the SCE and SCW wells at Bruce, the first drilled in the field since 2012. This is the ideal place to start as the wells can be tied backto existing sub-sea infrastructure to deliver a notable production increase from the asset around 12 months from the beginning of drilling andcapital spend at Bruce is highly tax efficient. Following this we have optionality about where the rig will go next, with a world-class subsurfaceteam identifying attractive drilling opportunities at Kyla and Glendronach, and also the possibility to drill further wells at Bruce, as well as to meetsome of our P&A obligations. With a total of six drilling slots expected, and rates of return of over 40%, we can't wait to get going. As Serica grows, with the acquisition of assets from Spirit Energy also set to increase our production and operated asset base, we have alsocontinued the scale-up of our internal capabilities. As well as bringing in some excellent people from the acquisitions we completed in the period,
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we were pleased to have recently welcomed Scott McGinigal to the team as Chief Operating Officer. Serica is expanding and we are confident thatwe have a team with the right experience, drive, and combination of skillsets to deliver on this growth and create an exceptional E&P company,focused on growth and delivering value for shareholders. A key growth area going forward is the West of Shetland basin, following the acquisition of the Greater Laggan Area from TotalEnergiescompleting in March. The acquisition brings operatorship of the Shetland Gas Plant, providing a strategic infrastructure position from which Sericacan pursue third-party throughput, near-field development and exploration opportunities. This creates a platform to build a material West ofShetland business. There is the possibility of significantly increasing throughput in the Shetland Gas Plant through additional third-party gas andinvestments in our own assets. The latter includes the Glendronach project and infill drilling at Tormore plus exciting exploration potential,assuming an appropriate fiscal and regulatory environment. Drilling at Bruce is highly tax efficient, and we are set to make a significant investment in the UK, supporting our supply chain as well as creatinga material opportunity for Serica. The programme can maintain annualised production of over 50,000 boepd from the UK into the next decade. TheUK North Sea remains the engine room of our business, and we continue to seek opportunities for further growth. Alongside this ambition, and complementary to it, we are also delighted to be making moves into jurisdictions overseas. The recently announcedrecommended offer for Pharos Energy is the first step in our longstanding strategic objective of adding to the diversification of our businessthrough international expansion. While there is a long way to go before we can be certain that this acquisition will complete, it would add valueaccretive growth on a per share basis across all key metrics, and provide us with a platform for further growth in the South East Asian region thatwe have previously flagged as being ideal for the pursuit of our strategy. This first step in overseas expansion is an exciting move for Serica, and isvery much one on which we firmly intend to build. This has been a positive and very active period for Serica, with plenty more to come, and I look forward to updating you on the numerous catalystsfor shareholder value creation ahead. REVIEW OF OPERATIONSIncreased portfolio reliability, plus the addition of production West of Shetland, led to a material increase to production in the period. TheLancaster field produced an average of just over 6,000 boepd prior to production ceasing as expected in early May. The addition of productionfrom GLA following completion of the acquisition from TotalEnergies on 26 March has helped retain a strong contribution from West of Shetlandthroughout the period. The GLA contribution, plus the Southern North Sea assets in Q4, are expected to increase the gas weighting of Serica'sportfolio from the 56% recorded in H1 2026, further enhancing exposure to UK gas markets. The acquisition of assets from Spirit Energy is now expected to complete on 1 October 2026, adding material production to the portfolio from ournew Southern North Sea Hub. Production (boepd) Q1 2026 Q2 2026 H1 2026 H1 2025 FY 2025Bruce Hub 17,700 18,500 18,100 16,700 16,100Triton Hub 11,100 20,300 15,700 2,500 5,900Other Producing Assets 4,200 5,000 4,600 5,500 5,300West of Shetland 6,200 6,400 6,300 - 300Total 39,200 50,200 44,700 24,700 27,600 Bruce HubBruce - Blocks 9/8a, 9/9b and 9/9c, Serica 98% and operatorRhum - Blocks 3/29a, Serica 50% and operatorKeith - Block 9/8a, Serica 100%Production from the Bruce Hub averaged 18,100 boepd (H1 2025: 16,700 boepd) net to the Company in the first half of the year. Asset uptime was86% in the period, and production benefitted from wells being returned to service following maintenance. The ability to regularly bullhead thewells has allowed production to be closer to the optimal level, averaging over 20,000 boepd in June. Work in the second half of 2026 will focus on the delivery of essential maintenance, improving the ongoing reliability of the asset throughremoving vulnerabilities and aiming to further optimise production going forward. The installation of an additional lifeboat will allow the numberof people working on the Bruce platform to increase, allowing an increase in work scopes. The annual maintenance period began on 1 August andis set to finish around the end of the month. Readiness work is also underway in preparation for drilling the first new wells at Bruce since 2012. A rig contract is expected to be signed shortly,with the drilling campaign set to start with the Bruce SCE and SCW wells in Q3 2027. Triton HubBittern - 64.63%, Evelyn - 100%, Gannet E - 100%, Guillemot West & North West - 10%, Belinda - 100%, Kyla - (P2616) Serica 100%and operatorThe Triton Hub produced 15,700 boepd (H1 2025: 2,500 boepd) net to Serica in the first half of 2026, benefitting from materially improvedperformance following significant maintenance work carried out in 2025. Following the resumption of production on 9 March after a 24 day outage for essential maintenance, asset uptime in the remainder of the periodwas over 95%, leading to production in the quarter of 20,300 boepd net to Serica. Production continued to be robust prior to the planned shutdownon Triton starting as scheduled on 27 July. The shutdown for key maintenance is expected by the operator, Dana, to last for approximately twomonths. Working with the operator, the focus remains on reliability and optimising production. There remains production potential at Triton above what iscurrently being produced, with only brief periods of production as yet from Belinda due to facility capacity constraints. The Kyla project, located in Block 29/2c, is the redevelopment of a previously producing oilfield, 20 km southeast of Triton, shut-in in 2020 solelydue to the decommissioning of the Banff FPSO host facility. Kyla contains 10.1 mmboe of 2P reserves and could be produced via a singlehorizontal well tied-back to Triton via Bittern, with the potential for first production within six months of the start of drilling. FEED commencedin February and has now concluded, and the environmental statement and field development plan have been submitted, in preparedness forpotential drilling as part of the Company's wider organic growth drilling campaign. West of ShetlandGreater Laggan Area ('GLA'), Serica 40% and operator
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Production from West of Shetland averaged 6,300 boepd net to Serica in the first half of 2026. The Lancaster field delivered the majority of theproduction in the period, averaging 6,100 boepd until production ceased as expected on 3 May 2026 due to the sail away of the Aoka Mizu FPSO. The acquisition of GLA from TotalEnergies completed on 26 March 2026, and contributed 4,200 boepd in Q2, with high uptime of 98%. Operatorship of the Shetland Gas Plant, the key processing infrastructure for one of the most prospective basins on the UK Continental Shelf, is akey factor in the significant growth potential for Serica West of Shetland. One potential development is the Glendronach project, part of GLA, ahigh-value short-cycle tie back opportunity, which is one of the candidates to form part of our organic growth drilling programme. Theenvironmental statement, the next step towards FID, is set to be submitted in Q3 2026. Discussions are also ongoing with the Tornado JV regardingtheir potential Tornado development. This would add material throughput, helping to extend the economic life of the plant. Other Producing AssetsProduction from our Other Producing Assets averaged 4,600 boepd in the first half of the year. Erskine - Blocks 23/26a (Area B) and 23/26b (Area B), Serica 18%The Erskine field continues to produce consistently, delivering a rate of 1,800 boepd net to Serica in H1 2026 (H1 2025: 2,100 boepd). Columbus - Blocks 23/16f and 23/21a (part), Serica 75% (operator)Production at Columbus has been steady in the first half of 2026, averaging 1,200 boepd (H1 2025: 1,500 boepd) net to Serica. Orlando - Block 3/3b, Serica 100%Orlando field production in H1 2026 averaged 1,000 boepd (H1 2025: 1,900 boepd) net to Serica, with production halting in May due to a failureof the Electrical Submersible Pump. Given the proximity to the scheduled closure of the Ninian platform in 2027, it has been determined that therequisite remedial activity would not be cost effective. As such, there will be no further production from the field, and we will be progressing toprepare for decommissioning and the P&A of the well in due course. Catcher - Serica 10%Golden Eagle Area Development - Serica 5.21%The acquisition from ONE-Dyas of a 10% interest in the Catcher field and a 5.21% interest in the Golden Eagle Area Development ('GEAD')completed on 10 June 2026. Since completion, Catcher has produced c.2,000 boepd net to Serica, and GEAD was producing c.500 boepd prior toentering its annual maintenance period on 4 July 2026, with maintenance set to end in mid-August. Other organic growth opportunitiesSkerryvore - Blocks 30/12c (part), 30/13c (split), 30/17h, 30/18c and 30/19c (part), Serica: 70% working interestThe P2400 Licence is located in the Central North Sea, 60 km south of the Erskine field. Skerryvore is a low-risk, multi-target explorationopportunity with significant upside, close to existing infrastructure with multiple tieback options. Plans are advancing to drill the well in 2027. Greater Buchan Area - Blocks 20/5a, 205d, 21/1d & 21/1a, Serica 30%Buchan Horst is one of the largest remaining undeveloped fields on the UKCS. Serica continues to evaluate development solutions within thecurrent fiscal landscape together with the operator, NEO NEXT+. P2530 (Wagtail) - Serica 40% (operator)Serica farmed-in to the P2530 licence in November 2025, to provide the opportunity to analyse the potential development of the Wagtail prospect.Following a portfolio review, Serica has elected to prioritise higher-return opportunities elsewhere in its portfolio and will therefore relinquish theP2530 licence with no further commitments. Fynn Beauly - (P2634) Serica 50%A 50% interest in the P2634 licence, containing the Fynn Beauly heavy oil discovery, was acquired when completing the acquisition of Parkmead(E&P) Limited in April 2025. The current licence commitment is limited to technical studies to assess potential development options. Acquisition of assets from Spirit EnergyThe acquisition of a Southern North Sea portfolio from Spirit Energy is now expected to complete on 1 October 2026, adding a new productionhub and further operated scale. Upon completion, the amount payable to Spirit Energy is estimated to be £38 million ($52 million), consisting ofthe upfront consideration of £57 million ($77 million) and customary completion adjustments, reduced by the interim post-tax cashflows betweenthe effective economic date of 1 January 2025 and the date of completion. Due to variability in commodity prices, asset performance and taximpacts, the amount of interim cash flow received is lower than previously forecast. The acquisition is expected to be immediately cash generative, with free cash flow from the assets now forecast to be over $200 million by the endof 2028, more than double the expectation upon announcement, due primarily to a stronger gas price outlook, a robust production outlook andrephasing of some interim period cash flows into the post-completion period. FINANCIAL REVIEWCash generation in the period has been robust and a material improvement from the same period last year, driven by a combination of muchimproved production performance (largely at the Triton Hub) and a strong commodity price backdrop - even after the impact of our hedgingportfolio. This generated revenues more than double the comparative H1 2025 period and both EBITDAX and post-tax CFFO very materiallyhigher than H1 2025, indeed higher than those metrics for the full year in 2025, with cash further boosted by the receipt of considerations oncompletion of acquisitions in the period and from financing activities. On an accounting basis, however, the period saw two material non-cash items in unrealised hedging and the expensing of certain goodwill chargesleading to a small loss before tax. These effects are largely offset through a net tax credit as a material deferred tax credit on the recognition ofdeferred tax assets on recent acquisitions offset an increased current tax charge, and hence the Company reported a modest net income for theperiod. From a funding and liquidity perspective, H1 2026 has been a very busy period as we completed our planned refinancing of the Company with thecompletion of our inaugural Nordic Bond in May and the completion of our refinanced RBL facilities shortly after the period end. We are well setup to approach the coming period of renewed investment in our portfolio as well as the completion and integration of the Spirit Energy assets and,subject to completion, the announced acquisition of Pharos Energy. Lastly, but by no means least, H1 2026 also saw us introduce a refreshed shareholder distribution policy applicable from FY 2026 onwards, basedon a payout ratio expressed as 15-30% of post-tax CFFO. The application of this policy will be applied in respect of the FY 2026 Final dividend,with the 6p per share declared today being taken into account in the full year dividend assessment.
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Summary of H1 2026 unaudited financial resultsAn analysis of the summary metrics provided in the Summary Financial Information table below is detailed in the following pages of this FinancialReview. Summary Financial Information Units H1 2026 H1 2025 Production and sales realised prices Production kboepd 44.7 24.7 Sales volumes mmboe 7.5 4.6 Natural Gas (net of NTS system charges) p/th 101 96 Crude Oil $/Bbl 93 70 NGLs $/MT 587 490 Income Statement Revenue $ million 677 305 EBITDAX(1) $ million 301 118 (Loss)/profit before taxation $ million (76) 101 Profit/(loss) after taxation $ million 6 (43) Basic earnings/(loss) per share cents 2 (11) Other key financial figures Capital expenditure(1) $ million 81 138 Operating cashflow $ million 271 102 Post tax CFFO(1) $ million 280 173 (1) See Reconciliation of non-IFRS measures for further detail. Production for H1 2026 was 44.7 kboepd, compared to 24.7 kboepd for H1 2025 with sales volumes of 7.5 mmboe (H1 2025: 4.6 mmboe). Theincrease primarily arose from improved production volumes from the Triton Area, which suffered material downtime in H1 2025, and the benefitof production from the newly acquired assets arising from the Prax Upstream acquisition in December 2025 and GLA assets in March 2026. Realised sales prices for oil for the period were materially higher than for H1 2025 with realised oil pricing pre-hedging averaging $93/bbl in H12026 (H1 2025: $70/bbl). NBP gas prices (net of NTS system charges) averaged 101p/th (H1 2025: 96p/th) as initial soft gas pricing in Januaryand February strengthened very significantly in the period on the back of the continued constraints in the Strait of Hormuz. However, the impact ofthe Company's hedge book, in place to ensure downside protection of the cost base with price floors of circa $60/bbl and 60p/therm, led toforegoing some of the commodity price upside with post-hedging realised prices of $73/bbl for oil and 97p/therm for gas. The combination ofthese volume and price impacts saw revenues of $677 million (H1 2025: $305 million), more than double the comparative period. The impact of increased production and higher prices was reflected at the adjusted profit level, with EBITDAX of $300.6 million compared to$118.5 million for H1 2025. However, reported accounting metrics in H1 2026 were impacted by significant non-cash charges arising from $111million of unrealised hedging losses (H1 2025: $53 million unrealised gains) and goodwill expense charges of $96 million (H1 2025: $nil). Lossbefore taxation of $75.6 million for H1 2026 compared to a profit before taxation of $100.8 million for H1 2025. Despite the pre-tax loss, the Group reported a profit after taxation of $6 million in H1 2026 (H1 2025: loss of $43 million), driven by a total taxcredit of $81.7 million (H1 2025: $144 million charge), comprising $59.9 million of current tax (H1 2025: $nil) and $141.6 million of deferred taxcredit (H1 2025: $144 million charge). The income statement deferred tax credit in H1 2026 included $95.6 million recognition of net deferred taxassets following the acquisition of new producing assets in the period. The deferred tax charge in H1 2025 included a one-off non-cash deferred taxexpense of $65 million as a result of the extension of the Energy Profits Levy to 31 March 2030 which was substantively enacted on 3 March 2025.Basic earnings per share was 2 cents (H1 2025: loss per share 11 cents). Operating cash flow also more than doubled to $271 million (H1 2025: $102 million), largely reflecting improved operating performance in theperiod. Capital expenditure was $81 million (H1 2025: $138 million) reduced from the prior period which included the completion of the five welldrilling programme at our Triton area assets. Sales revenues Revenue Units H1 2026 H1 2025 Total revenue $ million 677 305 Gas Sales $ million 294 207 Crude Oil $ million 358 87 NGLs $ million 16 11 Other revenue $ million 9 - Total H1 2026 revenue was $677.1 million, compared to H1 2025 revenue of $304.9 million. The increase in revenue was driven by both increasedproduction and pricing. Production increased from improved performance in the Triton area and the impact of new product streams arisingfollowing the Prax Upstream acquisition in December 2025 and subsequent asset acquisitions in March and June 2026 respectively. The increase inprices was primarily driven by the impact of global supply constraints caused by the war in Iran, resulting in stronger market prices for oil and gas. Sales comprised gas revenue of $293.9 million (H1 2025: $207.4 million), oil revenue of $358.4 million (H1 2025: $86.4 million) and NGLrevenue of $16.0 million (H1 2025: $11.1 million). The increase in gas revenue was driven by increased production and higher realised prices,similarly the oil revenue in the period was significantly higher than H1 2025, reflecting approximately 2.6 million bbls higher lifted volumes due tothe much improved Triton uptime, as well as significantly higher realised oil prices in the period ($93 per barrel as compared to $70 per barrel H12025). Like for like NGL revenues were also higher, impacted by increased sales volumes and higher realised prices for NGLs ($587 per metrictonne as compared to H1 2025: $490 per metric tonne).
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Sales revenues include other revenue of $8.8 million which reflects the Company's share of payments from the Victory field partners to the GLApartners for the processing of their gas in the Shetland Gas Plant, reflected from the 26 March 2026 GLA acquisition completion date. Total product sales volumes for the period comprised approximately 216 million therms of gas (H1 2025: 167 million therms), 3.8 million liftedbarrels of oil (H1 2025: 1.2 million barrels) and 29,200 metric tonnes of NGLs (H1 2025: 22,600 metric tonnes). This amounted to product sales inthe period of 7.5 million boe (H1 2025: 4.6 million boe). Gross profitThe gross profit for H1 2026 was $271.9 million compared to $76.4 million for H1 2025. Overall cost of sales of $405.2 million compared to$228.5 million for H1 2025. This comprised increased field operating and lifting costs of $246.5 million (H1 2025: $158.5 million), movements inoil over/underlift and oil inventory charges of $27.4 million (H1 2025: charge of $15.0 million), and $130.6 million of non-cash depletion charges(H1 2025: $54.9 million). Cost of sales Units H1 2026 H1 2025 Total operating costs $million 405 229 Field operating costs $million 240 156 Lifting costs $million 7 3 Movement in over / underlift $million 17 15 Movement in oil inventory $million 10 - DD&A $million 131 55 The increase in field operating costs reflects the increased scale of the business, including Lancaster operations before cessation in May, and threemonths post-acquisition GLA production. The Lancaster field ceased operations in May 2026 and hence its high operating costs inclusive of theleased FPSO charges will be removed from results going forward. Triton production was also much stronger in H1 2026 compared to H1 2025,although a significant proportion of the operating cost base is fixed in nature, some incremental operating and lifting costs are incurred in periodsof increased production. The charge from movement in oil inventory of $10.0 million arose from Lancaster operations. Operating costs as reportedwere approximately $30/boe, decreased from $35/boe for H1 2025, but inclusive of the circa $89/boe now ceased Lancaster costs. ExcludingLancaster, opex for the period was $25/boe. The increased H1 2026 production volumes also directly impact non-cash depletion charges which are calculated on a unit of production basis andconsequently increased by $75.7 million from $54.9 million in H1 2025 to $130.6 million in H1 2026. These effects were compounded by the average H1 2026 (£1: $1.34) period strength of sterling against the US dollar compared to H1 2025 (£1:$1.31) as most of the Group's operating costs are GBP-denominated. EBITDAX, operating profit before net finance costs and taxEBITDAX for H1 2026 was $301 million, over 2.5x higher than the $118 million for H1 2025. Operating profit to EBITDAX(1) Units H1 2026 H1 2025 Operating (loss)/profit $ million (50) 118Add back transaction costs $ million 3 -Add back DD&A and depreciation $ million 131 55 Add back E&E costs $ million - 1 Add back impairment of producing assets $ million 6 - Add back/(deduct) unrealised hedging $ million 111 (53) Deduct contract revenue - other $ million - (6) Add back share-based payments $ million 2 2 Add back goodwill expense $ million 96 - Add back/(deduct) FX effects/remeasurements $ million 2 1 EBITDAX(1) $ million 301 118 (1) See Reconciliation of non-IFRS measures for further detail. The operating loss for H1 2026 was $49.8 million compared to an operating profit of $118.1 million for H1 2025. The H1 2026 operating resultwas significantly impacted by non-cash charges for unrealised hedging and goodwill expense, both added back in the EBITDAX metric detailedabove. Net hedging expense of $199.4 million (H1 2025: net income of $51.8 million) comprised unrealised hedging losses of $110.8 million (H1 2025:$53.1 million gains) and realised hedging losses of $88.6 million (H1 2025: $1.4 million losses). Unrealised hedging losses arose from the non-cash movement in the mark-to-market valuation of commodity hedge positions at the period end to anet liability of $80.6 million. The main contributor being mark-to-market movements on oil and gas derivatives, driven by events in the MiddleEast. Serica has certain minimum hedging requirements for periods extending to the end of 2027 under the Group's RBL facility. Realised hedging expense in both periods related to oil and gas commodity derivatives settling during the period. Realised hedging expense in H12026 was mainly incurred in March, April and May, reflecting the exceptionally strong and volatile commodity pricing in those months and thecorresponding increased revenues as a result of the kinetic phase of the war in Iran.
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No contract revenue was recognised in H1 2026 (H1 2025: $5.4 million), as the fair value liability associated with an acquired revenue in 2023was fully unwound during 2025. Administrative expenses were $14.6 million in H1 2026, compared with $12.0 million in H1 2025. The increase was principally driven byadditional expenses associated with the integration of Prax Upstream and associated businesses in the Group's cost base. An expense of $95.6 million (H1 2025: $nil) was recognised in relation to the expense of goodwill arising on the Prax Upstream, GLA and ONE-Dyas acquisitions. During the period, previously unrecognised tax losses that had formed part of the initial goodwill recognised on acquisitionwere subsequently assessed as recoverable, resulting in the recognition of deferred tax assets and a corresponding reduction in goodwill which isexpensed through the Profit and Loss Statement. Loss before taxation and profit after taxation for the periodLoss before taxation for H1 2026 of $75.6 million (H1 2025: $100.8 million profit) included non-operating items of a $4.5 million charge arisingfrom an increase in the fair value of financial liabilities (H1 2025: $3.6 million charge), $1.4 million of finance revenue (H1 2025: $2.5 million)and $22.8 million of finance costs (H1 2025: $16.2 million). Finance revenue of $1.4 million (H1 2025: $2.5 million) primarily represented interest income earned on cash deposits and decreased as a result oflower average cash balances held in H1 2026 compared to H1 2025. Finance costs of $22.8 million (H1 2025: $16.2 million) included interestpayable and other charges on the RBL facility, interest on the recently issued Nordic Bonds, the non-cash discount unwind on decommissioningprovisions and other minor finance costs. The H1 2026 taxation credit of $81.7 million (H1 2025: $143.9 million charge) comprised current tax charges of $59.9 million (H1 2025: $nil) anda deferred tax credit of $141.6 million (H1 2025: $143.9 million charge). The current tax charge in H1 2026 was as a result of increased taxable profits arising from higher oil and gas revenue during the period. Thedeferred tax credit largely arose from the recognition in the period of deferred tax assets on tax losses available following the acquisition of newbusinesses. In 2025, current taxable income was fully sheltered by group relief impacts of tax losses within the Group, primarily due to the Triton Hub outagesas well as the application of capital allowances against the EPL charges resulting primarily from significant capital expenditure on the Belinda andEvelyn fields. The high H1 2025 deferred tax charge included the accounting impact of the enactment of the extension of the EPL to 2030 duringthat period. Reported and Effective tax rate Units H1 2026 H1 2025 (Loss)/profit before tax $ million (76) 101 Current tax charge $ million (60) - Deferred tax credit/(charge) $ million 142 (144) Tax credit/(charge) for the period $ million 82 (144) Book tax rate (108%) 143% Applicable ring-fence aggregate tax rate 78% 78% The Group generated a profit after taxation for H1 2026 of $6.1 million compared to a loss after taxation of $43.1 million (which included a one-off non-cash deferred tax charge of $65 million) for H1 2025. This corresponded to an earnings per share of 2 cents (H1 2025: loss per share of 11cents) after taking into account the weighted average number of ordinary shares in issue. GROUP BALANCE SHEETThe Group maintained access to its $525 million RBL facility with a refinanced $750 million RBL completed shortly after the period end on 23July. The Group benefitted from materially increased liquidity with the placement of its $300 million Nordic bond, and together with its cashreserves and cash generated in the period, was able to utilise its access to liquidity to fund ongoing capital investment, while continuing to supportshareholder returns. Following the period end, the Group announced the recommended acquisition of Pharos Energy in connection with which£128 million of cash was deposited in a DNB blocked account pending completion and will be reported as restricted cash pending a planned'certain funds' refinancing prior to completion. Assets 30 June 2026 31 December 2025 $ million $ million E&E 65 43 PP&E 1,146 1,156 Goodwill 50 56 Deferred tax asset 107 - Inventories 22 31 Trade and other receivables 232 171 Corporate tax receivable - 13 Derivative financial assets - 30 Cash & cash equivalents and restricted cash 326 31 Total Assets 1,948 1,531 Equity and liabilities 30 June 2026 31 December 2025 $ million $ million Equity 622 670 RBL borrowings, drawn amounts - 231
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Unsecured bonds 300 - Unamortised fees on RBL and bonds (16) (10) Corporate tax payable 55 - Deferred tax liability - 77 Provisions 516 252 Financial liabilities 105 94 Derivative financial liabilities 81 - Trade and other payables, lease liabilities 233 217 Dividend payable 52 - Total Equity and Liabilities 1,948 1,531 Total property, plant and equipment decreased marginally from $1,156 million at year end 2025 to $1,146 million at 30 June 2026. The decrease related to depletion charges of $130.6 million and an impairment charge on Orlando of $5.8 million following the decision not topursue uneconomic remedial activities on the field, partially offset by PP&E additions (comprising book capital expenditure during H1 2026,including accruals) of $68.2 million, acquisitions of $57.0 million (GLA $52.2 million and ONE-Dyas $4.8 million) and right-of use additions of$5.0 million. PP&E additions were primarily on the BKR Area ($49.0 million), Kyla development ($10.5 million) and Triton FPSO ($7.8 million).The overall decrease also included a $3.2 million currency translation adjustment. During H1 2026, Serica completed the acquisitions of a 40% operated interest in the Greater Laggan Area (GLA) from TotalEnergies and non-operated interests in the Catcher field (10%) and Golden Eagle Area Development (GEAD) (5.21%) from ONE-Dyas. Both acquisitions have beenaccounted for as business combinations in accordance with IFRS 3, with the excess of the purchase consideration over the provisional fair value ofthe identifiable net assets and liabilities assumed recognised as provisional goodwill. Provisional goodwill of $50.9 million was recognised on theacquisition of the GLA interest and $38.6 million on the acquisition of the ONE-Dyas interests. The decrease in goodwill balances recognised from$56.5 million at year-end to $50.4 million at 30 June 2026 reflects the incremental goodwill of $89.5 million recognised in H1 2026 transactionsless $95.6 million expensed following the recognition of deferred tax assets. The remaining goodwill balance as at 30 June 2026 primarily arisesfrom the requirements to recognise deferred tax on the difference between the fair value and the tax base of the assets acquired. The Balance Sheet net deferred tax asset of $106.6 million at 30 June 2026 compares to a net deferred tax liability of $77.1 million at year end2025. This comprised deferred tax assets in relation to tax losses, derivative liabilities on the hedging portfolio and future relief available ondecommissioning, offset by deferred tax liabilities arising on PP&E balances. The change from a net deferred tax liability position at 31 December2025 to a net deferred tax asset at the end of H1 2026 is largely a result of tax losses recognised on Prax Upstream losses following acquisitioncompletions and deferred tax assets now recognised on the mark-to-market hedging liabilities at 30 June 2026. Deferred tax liabilities arising uponthe Group's PP&E balances will be released in future periods as those balances are depleted. Following acquisitions in 2025, tax losses more than doubled in 2025, totalling $2.2 billion of ring fence Corporation Tax losses, $1.9 billion ofSupplementary Charge losses, and $0.5 billion of Energy Profits Levy ('EPL') losses as at 31 December 2025. Tax assets are held in entities acrossthe portfolio, with the exception of Serica Energy (UK) Limited, where the holding in the Bruce Hub creates particular scope for tax-efficientinvestment. Trade and other debtors increased to $232.1 million at 30 June 2026 from $171.0 million at 31 December 2025. The main driver behind theincrease was higher June revenues outstanding at the period end relative to December revenues outstanding at the year-end. The increase in cash and restricted cash from $31.0 million at 31 December 2025 to $325.9 million at 30 June 2026 reflected net cash inflow fromoperating activities of $273.8 million, $68.7 million of cash received on completion of the Total E&P and ONE-Dyas acquisitions, the $300 millioncash inflow (less fees and expenses) from the Nordic Bonds financing in May 2026, and is offset primarily by the repayment of existing RBLliabilities of $231.0 million and capital expenditure paid of $80.8 million. Current trade and other payables increased to $222.1 million at 30 June 2026 from $211.6 million at the end of 2025, reflecting growth in theGroup's activity. A corporation tax liability of $54.9 million (31 December 2025: $13.0 million receivable) was recognised at 30 June 2026, reflecting the Group'scurrent tax obligations arising from higher taxable profits driven by increased hydrocarbon production and revenues during the H1 2026period. The UK corporation tax receivable of $13.0 million at 31 December 2025 reflected a recovery of overpayments of corporation tax,supplementary charge, and the EPL in respect of 2025 resulting primarily from the application of group tax relief. The balance was substantiallyreceived in June 2026. The dividend payable of $51.9 million at 30 June 2026 (31 December 2025: $nil) represents the final cash dividend in respect of FY2025of 10 pence (13 cents) per share approved at the annual general meeting on 21 May 2026 and paid after the period end in July 2026. The net derivative financial liability of $80.6 million at 30 June 2026 represents the mark-to-market valuation of gas and oil commodity swap andcollar products in place at the period end. This is in contrast to the net derivative financial assets of $29.9 million at 31 December 2025. The swingfrom net assets to net liabilities is the result of the accounting impact of the significant increase in oil and gas forward curve prices over the period,resulting in a significant decrease in the fair value of the Group's commodity hedging portfolio. While higher forward commodity prices havereduced the fair value of the Group's hedging portfolio, the Group is expected to benefit from increased realised prices on unhedged productionvolumes, supporting future revenue and operating cash flows. Non-current and current financial liabilities of $105.2 million (31 December 2025: $93.9 million) comprise remaining deferred considerationprojected to be paid under the BKR acquisition agreements of $62.2 million (31 December 2025: $60.2 million), royalty liabilities of $26.4 million(31 December 2025: $24.8 million) for amounts payable to third parties under the terms of Triton asset acquisitions, deferred consideration relatingto the Parkmead acquisition of $5.2 million (31 December 2025: $8.9 million), and contingent consideration payable on the GLA acquisition of$11.4 million (31 December 2025: $nil). Provisions of $515.8 million (31 December 2025: $252.3 million) predominantly relate to future decommissioning obligations and comprisecurrent balances of $19.1 million (31 December 2025: $17.5 million) and non-current balances of $496.7 million (31 December 2025: $233.6million). The increase from the prior year balance of $252.3 million is primarily attributable to the GLA ($206.2 million) and ONE-Dyas ($66.0million) acquisitions, the unwinding of the discount applied, partially offset by minor currency translation effects.
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Interest bearing debt of $284.1 million at 30 June 2026 represents unsecured bonds of $300.0 million net of unamortised fees of $6.8 million, andremaining unamortised fees of $9.1 million on the Group's undrawn RBL facility (31 December 2025: RBL facility net $221.5 million) existing atthe Balance Sheet date. Overall, net assets have decreased from $669.6 million at year end 2025 to $621.9 million at 30 June 2026. CASH BALANCES AND FUTURE COMMITMENTS Current cash position and price hedgingAt 30 June 2026 the Group held adjusted net cash of $26 million as compared to adjusted net debt of $200 million at 31 December 2025. Adjusted Net Debt 30 June 2026 31 December 2025 $ million $ million Unsecured bonds and interest bearing loans (284) (221) Add back unamortised fees (16) (10)Cash, cash equivalents and restricted cash 326 31 Adjusted Net Cash/(Debt) 26 (200) HedgingSerica carries out hedging activity to manage commodity price risk, to meet its contracted arrangements under its RBL facility and to ensure thereis sufficient funding for future capital allocation objectives. Serica held the following instruments in respect of 2026 to 2028 for its existing assetsas at 30 June 2026: Oil hedges 2026 2027 Weighted Average: Units Q3-26 Q4-26 Q1-27 Q2-27 Q3-27 Q4-27 Swap price $/bbl 68 68 - - - - Collar floor net $/bbl 62 63 62 63 63 63 Total weighted average $/bbl 62 63 62 63 63 63 Collar ceiling $/bbl 71 72 71 71 71 71 Hedged Volume Kboe/d 15 23 19 16 15 15 Gas hedges 2026 2027 2028 Weighted Average: Units Q3-26Q4-26Q1-27Q2-27Q3-27Q4-27Q1-28Q2-28Q3-28 Collar floor net p/therm 61 66 66 55 55 60 60 59 59 Total weighted average p/therm 61 66 66 55 55 60 60 59 59 Collar ceiling p/therm 93 103 103 62 62 80 80 64 64 Hedged Volume Kboe/d 8 13 13 10 10 10 10 8 10 Field capital and other commitmentsSerica's remaining 2026 investment programme includes further capital work on the Bruce facilities and Triton FPSO. At 30 June 2026, the Group had commitments for future capital expenditure relating to its oil and gas properties which relate primarily to projectsbeing undertaken to increase the operational lifetime of both the Bruce and Triton hubs. The Group's only significant exploration commitmentwork programme includes drilling an exploration well on the Licence P2400 (Skerryvore) prospect regarding which, given the lack of clarityregarding the future fiscal and licensing regime, the licence was extended to 31 March 2027. Details of the Group's decommissioning obligations are included in note 11 of the Interim Financial Statements. In the normal course of business,the Group will obtain surety bonds, letters of credit and guarantees. At 30 June 2026, the Group held surety bonds totalling $354.3 million (31December 2025: $102.3 million) to provide security for its decommissioning obligations. With the conclusion of the Group's refinanced RBLwhich includes a dedicated $250 million LoC facility, we would expect to rebalance our decommissioning security for lower surety bond balancesand increased LoCs with the next decommissioning security renewals. Cash projections are run periodically to examine the potential impact of extended low oil and gas prices as well as possible productioninterruptions. Serica currently has substantial net cash resources and relatively low operating costs per boe which means that the Company is wellplaced to withstand such risks and its capital commitments can be funded from existing cashflow in most scenarios. Additional Information Additional information relating to Serica can be found on the Company's website at www.serica-energy.com and on SEDAR at www.sedar.com. Approved on behalf of the BoardChris CoxChief Executive Officer 5 August 2026
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Forward Looking Statements This disclosure contains certain forward looking statements that involve substantial known and unknown risks and uncertainties, some of whichare beyond Serica Energy plc's control, including: the impact of general economic conditions where Serica Energy plc operates, industryconditions, changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they areinterpreted and enforced, increased competition, the lack of availability of qualified personnel or management, fluctuations in foreign exchange orinterest rates, stock market volatility and market valuations of companies with respect to announced transactions and the final valuations thereof,and obtaining required approvals of regulatory authorities. Serica Energy plc's actual results, performance or achievement could differ materiallyfrom those expressed in, or implied by, these forward looking statements and, accordingly, no assurances can be given that any of the eventsanticipated by the forward looking statements will transpire or occur, or if any of them do so, what benefits, including the amount of proceeds, thatSerica Energy plc will derive therefrom. Serica Energy plcCondensed Consolidated Statement of Profit or Loss Six Sixmonths months Yearended ended ended30 June 30 June 31 December Notes 2026 2025 2025Continuing operations $000 $000 $000 Sales revenue 4 677,099 304,896 601,429 Cost of sales 5 (405,194) (228,523) (536,689) Gross profit 271,905 76,373 64,740 Unrealised hedging (losses)/gains 6 (110,843) 53,136 67,371Realised hedging (losses)/gains 6 (88,600) (1,350) 7,795Contract revenue - other - 5,408 5,408Exploration expense - (1,100) (1,100)E&E asset write-offs - (96) (147)Impairment of producing assets 10 (5,820) - -Administrative expenses (14,619) (11,976) (23,075)Foreign exchange (loss)/gain (1,526) (635) 38Transaction costs (3,048) - (5,533)Share-based payments (1,648) (1,673) (3,523)Expense of goodwill 16 (95,582) - - Operating (loss)/profit (49,781) 118,087 111,974 Change in fair value of financial liabilities (4,508) (3,587) (2,471)Finance revenue 1,455 2,473 6,102Finance costs 7 (22,771) (16,198) (35,262) (Loss)/profit before taxation (75,605) 100,775 80,343 Taxation credit/(charge) for the period 13 81,739 (143,869) (132,165) Profit/(loss) after taxation and profit/(loss) for the period 6,134 (43,094) (51,822) Earnings/(loss) per ordinary shareBasic EPS on profit/(loss) for the period ($) 0.02 (0.11) (0.13)Diluted EPS on profit/(loss) for the period ($) 0.02 (0.11) (0.13) Serica Energy plcCondensed Consolidated Statement of Comprehensive Income Six Sixmonths months Yearended ended ended30 June 30 June 31 December 2026 2025 2025 $000 $000 $000 Profit/(loss) for the period 6,134 (43,094) (51,822) Other comprehensive (loss)/profit
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Exchange differences on translation (3,574) 20,774 15,909 Other comprehensive (loss)/profit for the period (3,574) 20,774 15,909 Total comprehensive income/(loss) for the period 2,560 (22,320) (35,913) Total comprehensive income/(loss) attributable to:Equity owners of the Company 2,560 (22,320) (35,913) Serica Energy plcCondensed Consolidated Statement of Financial Position 30 June 31 December2026 2025$000 $000NotesNon-current assetsExploration & evaluation assets 9 64,858 43,283Property, plant and equipment 10 1,145,707 1,155,716Goodwill 16 50,448 56,497Derivative financial assets 6 - 5,667Deferred tax asset 13 106,557 -1,367,570 1,261,163Current assetsInventories 22,124 31,423Trade and other receivables 232,095 170,993Corporate tax receivable - 13,026Derivative financial asset 6 - 24,260Restricted cash 1,460 12,060Cash and cash equivalents 324,451 18,840580,130 270,602 TOTAL ASSETS 1,947,700 1,531,765 Current liabilitiesTrade and other payables 222,124 211,646Derivative financial liability 6 50,581 -Corporate tax payable 54,923 -Financial liabilities 5,164 4,140Lease liabilities 3,683 2,308Dividends payable 8 51,897 -Provisions 11 19,109 18,712 Non-current liabilitiesDerivative financial liabilities 6 30,048 -Financial liabilities 100,041 89,756Deferred tax liability 13 - 77,132Lease liabilities 7,388 3,415Provisions 11 496,718 233,594Loans and borrowings 12 284,139 221,488TOTAL LIABILITIES 1,325,815 862,191 NET ASSETS 621,885 669,574 Share capital 14 245,715 245,715Merger reserve 14 286,590 286,590Other reserves 42,711 41,063Treasury/own shares (3,397) (6,678)Accumulated funds 52,043 101,087Currency translation reserves (1,777) 1,797 TOTAL EQUITY 621,885 669,574 Serica Energy plcCondensed Consolidated Statement of Changes in Equity
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Sharecapital Merger reserve Other reserves Treasury/ownshares Currencytranslationreserve Accumulatedfunds Total $000 $000 $000 $000 $000 $000 $000 At 1 January 2025 245,537 286,590 37,540 (8,931) (14,112) 249,834 796,458 Loss for the year - - - - - (51,822) (51,822)Other comprehensive income - - - - 15,909 - 15,909Total comprehensive income - - - - 15,909 (51,822) (35,913) Issue of shares 178 - - - - - 178Share-based payments - - 3,523 - - - 3,523Treasury/own shares - - - (9,819) - - (9,819)Release of shares - - - 12,072 - (12,072) -Dividend payable - - - - - (84,853) (84,853) At 31 December 2025 245,715 286,590 41,063 (6,678) 1,797 101,087 669,574 Profit for the period - - - - - 6,134 6,134 Other comprehensive loss - - - - (3,574) - (3,574)Total comprehensive income - - - - (3,574) 6,134 2,560 Issue of shares - - - - - - -Share-based payments - - 1,648 - - - 1,648Treasury/own shares - - - 213 - - 213Release of shares - - - 3,068 - (3,281) (213)Dividend payable - - - - - (51,897) (51,897) At 30 June 2026 245,715 286,590 42,711 (3,397) (1,777) 52,043 621,885 Serica Energy plcCondensed Consolidated Cash Flow Statement Six Sixmonths months Yearended ended ended30 June 30 June 31 December2026 2025 2025$000 $000 $000Note Cash inflow from operations 15 270,493 101,954 179,946Taxation received/(paid) 9,126 70,554 63,358Decommissioning spend (5,847) (104) (1,088)Net cash inflow from operating activities 15 273,772 172,404 242,216 Investing activities:Interest received 1,455 2,473 5,486Purchase of E&E assets (1,370) (1,179) (6,467)Purchase of property, plant & equipment (79,427) (136,527) (242,567)Acquisition of asset interests (4,168) (10,416) (11,720)Business combination, net cash received/acquired 16 68,682 - 2,235Net cash outflow from investing activities (14,828) (145,649) (253,033) Financing activities:Payments of lease liabilities (2,071) - (1,943)Proceeds from share issues - 178 178Repayment of borrowings (231,000) - (51,848)Proceeds from borrowings - net 293,199 (979) 51,848Dividends paid - - (84,853)Share buyback - - (9,819)Finance costs paid (11,361) (11,620) (25,900)Net cash outflow from financing activities 48,767 (12,421) (122,337) Cash and cash equivalentsNet increase/(decrease) in period 307,711 14,334 (133,154)Effect of exchange rates on cash and cash equivalents (2,100) 11,601 3,534 Amount at start of period 18,840 148,460 148,460Amount at end of period 324,451 174,395 18,840 Serica Energy plc
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Notes to the Condensed Consolidated Financial Statements 1. Corporate informationThe interim condensed consolidated financial statements of the Group for the six months ended 30 June 2026 were authorised for issue in accordance with aresolution of the directors on 5 August 2026. Serica Energy plc ('the Company') is a public limited company incorporated and domiciled in England & Wales. The Company's ordinary shares are tradedon the AIM in London. The principal activity of the Company is to identify, acquire and exploit oil and gas reserves. 2. Basis of preparation and accounting policies Basis of preparationThe interim condensed consolidated financial statements for the six months ended 30 June 2026 have been prepared in accordance with InternationalAccounting Standard 34 'Interim Financial Reporting'. These unaudited financial statements of the Group have been prepared following the same accounting policies and methods of computation as theconsolidated financial statements for the year ended 31 December 2025. These financial statements do not include all the information and footnotes requiredby generally accepted accounting principles for annual financial statements and therefore should be read in conjunction with the consolidated financialstatements and the notes thereto in the Serica Energy plc annual report for the year ended 31 December 2025. The financial information contained in this announcement does not constitute statutory financial statements within the meaning of section 435 of theCompanies Act 2006. Going concernThe Directors are required to consider the availability of resources to meet the Group's liabilities for the period ending 30 September 2027, the 'going concernperiod'. As at 30 June 2026 the Group held cash and cash equivalents of $324.5 million, and restricted cash of $1.5 million and undrawn committed capacity under its$525 million RBL facility amount of $456 million. Subsequent to the period end the Group entered into a new RBL facility (see note 12). The Group has a balance in product mix between gas and oil, and two main operating hubs which reduces the potential impact of production interruptions.The Group regularly monitors its cash, funding and liquidity position, including available facilities and compliance with facility covenants. Ongoing capitalrequirements also include surety bonds which provide cover for decommissioning security. Near-term cash projections are revised and underlyingassumptions reviewed, generally monthly, and longer-term projections are also updated regularly. Downside price and other risking scenarios are considered.In addition to commodity sales prices the Group is exposed to potential production interruptions and these are also considered under such scenarios. In recentyears, management has given priority to building a strong cash reserve which can respond to different types of risk. For the purposes of the Group's going concern assessment two cash projection cases have been reviewed for the going concern period. These projectionscover a base case forecast and an extreme stress test scenario for the operations of the Group. No covenant compliance breaches within the RBL or theNordic bond were noted. The base case assumptions for the going concern period included average commodity pricing of 94 pence/therm for gas and US$73/bbl for oil across theperiod. Production, opex, capex and tax assumptions are those currently included in standard management forecasting. The forward-looking priceassumptions are considered reasonable in light of recent commodity forward pricing and a consensus of published forecasts from the industry, brokers andother analysts. The stress test assumptions assume a five month period shut-in of Triton hub production across Q3 and Q4 2026. From Q1 to Q3 2027, a 25% reduction toproduction volumes relative to the base case across the full portfolio of producing assets is applied. Base case commodity pricing is retained for 2026 butlower commodity pricing of 50 pence/therm gas and US$60/bbl oil are assumed for the Q1 to Q3 2027 periods in this scenario which are significantly belowthe range of current market expectations for the going concern period. Under this downside scenario, which assumes lower-than-expected cash inflows, theGroup maintained sufficient liquidity to meet its obligations as they fall due throughout the going concern assessment period. A number of mitigating factorsand actions that are under management control are available to management in the stress test event. These would mitigate the reduced operating cashoutflows experienced and are not included in the projection. After making enquiries and having taken into consideration these factors, the Directors considered it appropriate that the Group has adequate resources tocontinue in operational existence for the going concern period. Accordingly, they continue to adopt the going concern basis in preparing the financialstatements. Significant accounting policiesA number of new standards, amendments to existing standards and interpretations were applicable from 1 January 2026. The adoption of these amendmentsdid not have a material impact on the Group's interim condensed consolidated financial statements for the period ended 30 June 2026. The accounting policies adopted in the preparation of the interim condensed consolidated financial statements are consistent with those followed in thepreparation of the Group's annual financial statements for the year ended 31 December 2025. The impact of seasonality or cyclicality on operations is notconsidered significant on the interim consolidated financial statements. The Group financial statements are presented in $ and all values are rounded to the nearest thousand except when otherwise indicated. Use of judgement and estimates and sources of estimation uncertaintyThe preparation of financial statements in conformity with UK adopted International Accounting Standards requires management to make judgements andestimates that affect the reported amounts of assets and liabilities as well as the disclosure of contingent assets and liabilities at the balance sheet date and thereported amounts of revenues and expenses during the reporting period. Estimates and judgements are continuously evaluated and are based onmanagement's experience and other factors, including expectations of future events that are believed to be reasonable under the circumstances. Actualoutcomes could differ from these estimates. The areas for the Group where significant judgement, estimates, and assumptions are required are consistent withthose reported in the Group's annual financial statements for the year ended 31 December 2025 but now include a key source of estimation uncertainty inrespect of acquisition accounting, noted below. Key source of estimation uncertainty - Purchase Price Allocation for acquisitionsDetermining the fair value of the identifiable net assets acquired in a business combination required the use of significant estimates and assumptions.Management applies discounted cash flow techniques to value acquired oil and gas assets and related obligations, incorporating assumptions relating tofuture production profiles, commodity prices, operating costs, discount rates and decommissioning liabilities. Given the inherent uncertainty in forecastingthese factors, changes in market conditions, reserve estimates or operational performance could result in material adjustments to the fair values assigned and,consequently, the amount of goodwill recognised.
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Basis of consolidationThe interim consolidated financial statements include the accounts of Serica Energy plc (the 'Company') and entities controlled by the Company (itssubsidiaries) made up for the six month period to 30 June each year. Together these comprise the 'Group'. Control is achieved when the Company:• has power over the investee;• is exposed, or has rights, to variable returns from its involvement with the investee; and• has the ability to use its power to affect its returns. The Company reassesses whether or not it controls an investee if facts and circumstances indicate that there are changes to one or more of the three elementsof control listed above. Consolidation of a subsidiary begins when the Company obtains control over the subsidiary and ceases when the Company losescontrol of the subsidiary. Specifically, the results of the subsidiaries acquired or disposed of during the year are included in profit or loss from the date theCompany gains control until the date when the Company ceases to control the subsidiary. The results and financial position of all of the Group entities that have a functional currency different from the presentation currency are translated into thepresentation currency as follows: · Assets and liabilities for each balance sheet presented are translated at the closing rate at the date of that balance sheet;· Income and expenses for each income statement are translated at average exchange rates (unless this average is not a reasonable approximation of therates prevailing on the transaction dates, in which case income and expenses are translated at the rate on the dates of each transaction);· The exchange differences arising on translation for consolidation are recognised in other comprehensive income; and· Any fair value adjustments to the carrying amounts of assets and liabilities arising on the acquisition are treated as assets and liabilities of the acquiredentity and are translated at the spot rate of exchange at the reporting date. All inter-company balances and transactions have been eliminated upon consolidation. 3. Segmental informationFor the purposes of segmental reporting, the Group currently operates a single class of business being oil and gas exploration, development and productionand related activities in a single geographical area, being presently the UK North Sea. 4. Sales revenue Sixmonths Sixmonths Yearended ended ended30 June 30 June 31 December2026 2025 2025$000 $000 $000 Gas sales 293,854 207,410 360,925Oil sales 358,399 86,403 218,984NGL sales 16,040 11,083 21,520Sub-total 668,293 304,896 601,429 Other revenue 8,806 - - Total revenue 677,099 304,896 601,429 5. Cost of sales Sixmonths Sixmonths Year ended ended ended 30 June 30 June 31 December2026 2025 2025$000 $000 $000 Operating costs 239,421 156,069 366,605Lifting costs 7,110 2,499 8,006Change in decommissioning estimates expensed 590 - -Movement in liquids overlift /(underlift) 17,355 15,023 9,660Depletion (note 10) 130,630 54,932 158,141Movement in oil inventory 10,088 - (5,723) 405,194 228,523 536,689 6. Derivative Financial (Liabilities)/Assets 30 June2026 31 December2025$000 $000Financial assetsDerivative financial instruments (<1 year) - 24,260Derivative financial instruments (>1 year) - 5,667
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Derivative financial instruments - 29,927 Financial liabilitiesDerivative financial instruments (<1 year) 50,581 -Derivative financial instruments (>1 year) 30,048 - Derivative financial instruments 80,629 - Fair value hierarchyAll financial instruments for which fair value is recognised or disclosed are categorised within the fair value hierarchy, based on the lowest level input that issignificant to the fair value measurement as a whole, as follows: Level 1: Quoted (unadjusted) market prices in active markets for identical assets orliabilities; Level 2: Valuation techniques for which the lowest level input that is significant to the fair value measurement is directly (i.e. as prices) orindirectly (i.e. derived from prices) observable; Level 3: Valuation techniques for which the lowest level input that is significant to the fair valuemeasurement is unobservable. The valuation methodology for derivative financial instruments is detailed below. Derivative financial instrumentsThe Group enters into derivative financial instruments with various counterparties. Commodity and foreign currency derivative contracts are designated as atfair value through profit or loss (FVTPL), and gains and losses on these contracts are recognised in the income statement. Derivative financial instrumentsheld at 30 June 2026 and 31 December 2025 comprised swaps and collars for both oil and gas volumes. These were valued by counterparties, with thevaluations reviewed internally and corroborated with readily available market data of forward pricing (level 2). The mark-to-market of the Group's open contracts as at 30 June 2026 was a net liability of $80.6 million (31 December 2025: net asset of $29.9 million). Six months Six months Yearended ended ended30 June 30 June 31 December2026 2025 2025$000 $000 $000 Unrealised hedging (losses)/gains (110,843) 53,136 67,371 Realised hedging (losses)/gains (88,600) (1,350) 7,795 Hedging (expense)/income (199,443) 51,786 75,166 Unrealised hedging losses in 2026 arose from oil and gas instruments held (2025: gains on oil and gas instruments). Unrealised hedging losses on gas andother swaps comprise unrealised charges on the movement during the period/year in the calculated fair value liability and asset of outstanding gas price orother derivative contracts measured at the respective balance sheet dates. Realised hedging losses measured at fair value through profit or loss for 2026 comprise losses realised on oil and gas swaps. For 2025 gains were realised onoil and gas swaps. 7. Finance costs Six months Six months Year ended ended ended 30 June 30 June 31 December2026 2025 2025 $000 $000 $000 Loan interest payable 12,507 9,556 19,194 Commitment and other financing fees 2,809 2,377 6,415 Other charges and interest payable 1,155 1,006 3,016 Unwinding of discount on provisions (note 11) 6,300 3,259 6,637 Total finance costs 22,771 16,198 35,262 8. Dividends payableA final cash dividend for 2025 of 10.0 pence (13.0 cents) per share was proposed in March 2026 and approved at the annual general meeting on 21 May2026. Following the approval in the H1 2026 period, the dividend payable of £39 million ($52 million) is recognised as a liability in the Balance Sheet at 30June 2026. The dividend was paid in July 2026. Dividends on ordinary shares paid in 2025A final cash dividend for 2024 of 10.0 pence per share was proposed in April 2025 and approved at the annual general meeting on 22 May 2025 and $53.9million (£39.3 million) was paid in July 2025. An interim cash dividend for 2025 of 6.0 pence per share was announced in August 2025 and $31.0 million (£23.5 million) was paid in November 2025. 9. Exploration and evaluation assets Total
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$000Cost:At 1 January 2025 20,367 Acquisitions 19,391Additions 6,467Transfers (4,694)Asset write-offs (147)Currency translation adjustment 1,899 At 31 December 2025 43,283 Acquisitions (note 16) 20,912Additions 1,370Currency translation adjustment (707) At 30 June 2026 64,858 Net Book Amount: 30 June 2026 64,858 31 December 2025 43,283 1 January 2025 20,367 10. Property, plant and equipment Oil and gasproperties Fixturesand fittings Right-of-useassets Total$000 $000 $000 $000 Cost:At 1 January 2025 1,575,603 266 10,297 1,586,166 Acquisitions 1,877 - - 1,877Additions 257,410 - 791 258,201Transfers 4,694 4,694Decommissioning asset revisions 41,676 - - 41,676Currency translation adjustment 42,746 20 444 43,210 31 December 2025 1,924,006 286 11,532 1,935,824 Acquisitions (note 16) 54,840 - 2,173 57,013Additions 68,223 - 5,049 73,272Currency translation adjustment (11,032) (5) (183) (11,220) At 30 June 2026 2,036,037 281 18,571 2,054,889 Depreciation and depletion:At 1 January 2025 590,414 266 3,898 594,578 Charge for the year (note 5) 157,101 - 1,040 158,141Charge for the year - other - - 1,045 1,045Currency translation adjustment 26,150 20 174 26,344 At 31 December 2025 773,665 286 6,157 780,108 Charge for the period (note 5) 129,880 - 750 130,630Provision for impairment 5,820 - - 5,820Charge for the period - other - - 644 644Currency translation adjustment (7,953) (5) (62) (8,020) At 30 June 2026 901,412 281 7,489 909,182 Net book amount:At 30 June 2026 1,134,625 - 11,082 1,145,707 At 31 December 2025 1,150,341 - 5,375 1,155,716 At 1 January 2025 985,189 - 6,399 991,588 Depreciation and depletionDepletion charges on oil and gas properties are calculated on a unit of production method based on commercial proved and probable reserves and areclassified within 'cost of sales'. Depreciation on other elements of property, plant and equipment is provided on a straight-line-basis and taken throughadministration expenses.
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Provision for impairmentThe $5.8 million provision for impairment relates to the Orlando asset in the UK North Sea. Production at Orlando halted in May 2026 and, following adecision not to proceed with remedial activity, there will be no further production from the field. 11. Provisions Decommissioning Other provision provision Total$000 $000 $000 At 1 January 2025 145,659 315 145,974 Acquisitions 56,480 - 56,480Change in estimate 41,676 - 41,676Unwinding of discount 6,637 - 6,637Utilisation (1,088) (108) (1,196)Additions - 987 987Currency translation adjustment 1,748 - 1,748 At 31 December 2025 251,112 1,194 252,306 Acquisitions (note 16) 272,165 - 272,165Change in estimate 590 - 590Unwinding of discount (note 7) 6,300 - 6,300Utilisation (15,136) - (15,136)Currency translation adjustment (394) (4) (398) At 30 June 2026 514,637 1,190 515,827 Classified as:Current 17,919 1,190 19,109Non-current 496,718 - 496,718 At 30 June 2026 514,637 1,190 515,827 Classified as:Current 17,518 1,194 18,712Non-current 233,594 - 233,594 At 31 December 2025 251,112 1,194 252,306 Decommissioning provisionThe decommissioning provision represents the present value of decommissioning costs relating to oil and gas interests in the UK which are expected to beincurred up to 2036. The Group recognised decommissioning provisions of $272.2 million on acquisitions in the period, comprising $206.2 million in respect of its 40% operatedinterest in the Greater Laggan Area (GLA), relating to the Laggan, Tormore, Glenlivet, Edradour, and Glendronach producing fields (note 16.2), and $66.0million in respect of the acquired non-operated interests in Catcher ($34.1 million) and the Golden Eagle Area Development (GEAD) ($31.9 million) (note16.3). The provision estimates were based principally on external party reports, where applicable, supplemented by internal assessments prepared by Serica'stechnical team. 12. Loans and borrowings The Group's loans and borrowings are carried at amortisedcost as follows: 30 June 2026 31 December 2025 Principal Fees Total Principal Fees Total $000 $000 $000 $000 $000 $000 Unsecured bonds 300,000 (6,801) 293,199 - - -Reserve based lending - (9,060) (9,060) 231,000 (9,512) 221,488Total borrowings 300,000 (15,861) 284,139 231,000 (9,512) 221,488 Due within one year - -Due after more than one year 284,139 221,488Total borrowings 284,139 221,488 Nordic bonds placedOn 12 May 2026, the Group successfully completed the placement of senior unsecured bonds issued by the Company with a principal amount of US$300.0million and a maturity of five years. The bonds bear interest at a fixed coupon rate of 7.875% per annum, payable 6-monthly in arrears.
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The net proceeds from the bonds were used primarily to repay in full the outstanding drawn balance under the Group's Reserve Based Lending (RBL) facilityand to strengthen the Group's liquidity position. Reserves based lendingIn July 2026, Serica completed a new six-year senior secured RBL facility of $750 million comprising a $500 million secured revolving loan (Loan) facilityand a $250 million secured revolving letter of credit ('LoC') facility. The RBL facility provides significant liquidity to support future acquisitions andinvestments. The new facility replaces the Group's previous $525 million RBL facility and provides extended maturity and improved pricing terms, and hasan initial borrowing base, pro forma for the Spirit Energy assets, of $458 million. The RBL has a maturity date of 30 June 2032 but with a springing maturity linked to the maturity of the bond, with amortisation commencing on 30 June2029. The interest rate for loan drawings is SOFR plus a margin of 3.5% per annum and the available amount under the facility is subject to semi-annualredeterminations. The new facility includes a $250 million limit which can be utilised to issue Letters of Credit in relation to Borrowing Base assets withoutthe need for cash security. The new facility also includes a further uncommitted accordion feature providing access to an additional $750 million, comprising up to $500 million on theLoan facility and up to US$250 million on the LoC facility, taking potential total facilities to $1,500 million. The RBL includes a financial covenant to maintain net debt/EBITDAX cover ratio below 3.5 and other terms and conditions are consistent with Loan MarketAssociation terms for comparable syndicated RBL financings. 13. Taxation The major components of income tax charged in the consolidated income statement are: Six months Six months Year ended ended ended 30 June 30 June 31 December 2026 2025 2025 $000 $000 $000 Current income tax charge 59,855 - 1,761 Deferred income tax (credit)/charge (141,594) 143,869 130,404 Total taxation (credit)/charge for the period (81,739) 143,869 132,165 The deferred tax included in the Balance Sheet is as follows: 30 June2026 31 December2025 $000 $000 Deferred tax assets 818,829 635,798 Deferred tax liabilities (712,272) (712,930) Total deferred tax asset/(liability) 106,557 (77,132) Reconciliation of net deferred tax asset/(liability) for theperiod: $000 At 1 January 2026 (77,132) Tax credit for the period recognised in profit (note 16.4) 141,594Net deferred tax on acquisition (note 16.5) 40,381 Currency translation adjustment 1,714 At 30 June 2026 106,557 Tax lossesThe Group's Condensed Consolidated Statement of Financial Position has recognised a deferred tax asset amount of $818.8 million as at 30 June 2026 (31December 2025: $635.8 million) arising from ring-fence losses, decommissioning liabilities and other temporary differences. These deferred tax assets areexpected to be recovered through utilisation against deferred tax liabilities, primarily related to temporary differences on fixed assets and through futuretaxable profits. The Group's deferred tax assets at 31 December 2025 and 30 June 2026 are recognised to the extent that taxable profits are expected to arise in the futureagainst which tax losses and allowances in the UK can be utilised. In accordance with IAS 12 Income Taxes, the Group assessed the recoverability of itsdeferred tax assets at 30 June 2026 with respect to ring fence losses and allowances. Changes to UK corporation tax legislationIn October 2024, the UK Government announced changes (effective from 1 November 2024) to the Energy Profits Levy ('EPL'), including a 3% increase inthe rate taking the headline rate of tax on North Sea profits to 78%, an extension to the period of application of the EPL to 31 March 2030 and the removal ofthe EPL's main investment allowance. The changes to the rate and to the investment allowance were substantively enacted in November 2024 and have beenapplied in both 2024 and 2025, and 2026 interim when accounting for current tax and deferred tax.
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The extension of the EPL to 31 March 2030 was substantively enacted on 3 March 2025 and was reflected in the 2025 interim and full year financialstatements. The impact of the extension was an additional deferred tax expense of $65 million. Following the introduction of the EPL in 2022, on 24 May 2024, Finance (No.2) Act 2024 enacted the Energy Security Investment Mechanism ('ESIM'). Theoriginal ESIM threshold prices were $71.40 per barrel for oil and 54 pence per therm for gas. These thresholds were based on a 20-year average to the end of2022. These thresholds were adjusted from 1 April 2024, and will be adjusted annually thereafter, by the preceding December's year-on-year increase in theConsumer Prices Index. The ESIM operates to remove EPL if both average oil and gas prices fall to, or below, $78.65 per barrel for oil and 61p per therm forgas from 1 April 2026, for two consecutive quarters. On 13 July 2026, the UK Government published draft legislation ahead of Finance Bill 2026-27 (the 'Finance Bill') with regards to the Oil and gas revenuelevy ('OGRL') (which was formerly referred to as the oil and gas price mechanism ('OGPM')) that will apply at a rate of 35% to oil and gas revenues earnedabove specified thresholds (initially $90 per barrel for oil and 90 pence per therm for gas for the financial year ended 31 March 2027, but subject to certainadjustments in relation to hedging) and which is intended to replace the EPL. The OGRL will take effect the day after the EPL ceases, being the earlier of 31 March 2030 or any earlier date triggered by the ESIM. As at the reportingdate, given that the relevant legislation remains in draft and has therefore not been substantively enacted, the impact of the OGRL has not been reflected inthe measurement of current or deferred tax balances in accordance with IAS 12 Income Taxes. Accordingly, the proposed legislative changes have had noimpact on the Group's tax charge, deferred tax balances or results for the interim period. The UK has also implemented the Organisation for Economic Co-operation and Development's ('OECD') proposals for global minimum corporation tax rate(Pillar Two) which is effective for periods beginning on or after 31 December 2023. The only jurisdiction in which the Group currently has materialoperations is the UK, and the Group does not expect any exposure to Pillar Two income taxes. 14. Equity share capitalAs at 30 June 2026, the share capital of the Company comprised one 'A' share of £50,000 and 393,568,407 ordinary shares of $0.10 each. The 'A' share hasno special rights. The balance classified as total share capital includes the total net proceeds (both nominal value and share premium) on issue of the Group and Company'sequity share capital, comprising $0.10 ordinary shares and one 'A' share. Allotted, issued and fully paid: Share Share Total share Merger Number capital premium capital reserveGroup '000 $000 $000 $000 $000 At 1 January 2025 393,468 39,347 206,190 245,537 286,590 Shares issued 100 10 168 178 - At 31 December 2025 393,568 39,357 206,358 245,715 286,590 Shares issued - - - - - At 30 June 2026 393,568 39,357 206,358 245,715 286,590 During H1 2026, nil ordinary shares were issued to satisfy awards under the Company's share-based incentive schemes. Group merger reserveMerger relief was applied by the Group's parent entity Serica Energy plc upon the respective issues of 108,170,426 ordinary shares in March 2023, 1,438,849ordinary shares in September 2023 and 1,438,849 ordinary shares in March 2024, for the acquisition of Tailwind Energy Investments Ltd. The valuation ofthe shares issued was based on the fair value at the date of issue, with the nominal value of the shares issued credited to share capital and the excess value of$286.6 million (£230.3 million) above nominal share capital credited to a merger reserve in the consolidated Group accounts. Treasury/own shares reserveTreasury and own shares represent Serica shares repurchased and available for specific and limited purposes. A balance of 1,656,724 own shares (31December 2025: 3,013,783 treasury shares) included in the reserve of $3,397,000 is held at 30 June 2026 (31 December 2025: $6,678,000). The Companypurchased nil ordinary shares during 2026. 15. Additional cash flow information Net cash flows from operating activities consist of: Six Sixmonths months Yearended ended ended30 June 30 June 31 December2026 2025 2025$000 $000 $000 Operating activities:Profit/(loss) for the period 6,134 (43,094) (51,822)Adjustments to reconcile profit/(loss) for theperiod to net cash flow from operating activities:Taxation (credit)/charge (81,739) 143,869 132,165Change in fair value of financial liabilities 4,508 3,587 2,471
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Change in provisions 590 - 987Net finance costs 21,316 13,725 29,160Depletion and depreciation 131,274,274 55,447 159,186 Oil and NGL over/underlift movement 17,355 15,023 9,660E&E asset write-offs - 96 147Impairment of producing assets 5,820 - -Unrealised hedging losses/(gains) 110,843 (53,136) (67,371)Contract revenue - other - (5,408) (5,408)Share-based payments 1,648 1,673 3,523Expense of goodwill (note 16) 95,582 - -Other non-cash movements (1,284) 1,437 111Decrease in restricted cash 10,600 - -(Increase)/decrease in receivables (69,926) (9,616) (10,826)Decrease/(Increase) in inventories 7,088 (605) (7,562)Increase/(decrease) in payables 10,684 (21,044) (14,475) Cash inflow from operations 270,493 101,954 179,946Taxation received 9,126 70,554 63,358Decommissioning spend (5,847) (104) (1,088)Net cash inflow from operating activities 273,772 172,404 242,216 16. Business Combinations 16.1 Prax Upstream Limited Overview of the transactionOn 11 December 2025, the Company completed the acquisition of 100% of the shares of Prax Upstream Limited (PUL) for a purchase consideration of $19.6million and as a result of this acquisition Serica held a 100% operated interest in the Lancaster field in the West of Shetland Area. The acquisition isconsidered to constitute a business as defined in IFRS 3 Business Combinations and is therefore accounted for as a business combination. At the acquisition date PUL was party to separate executed Sale and Purchase Agreements ('Existing SPAs') with TotalEnergies and ONE-Dyas for thepurchase of certain assets for base consideration payable of $1 and $6.75 million respectively. The base consideration in both transactions was adjusted bycustomary completion adjustments in the interim period. Completion of the Existing SPAs occurred in H1 2026, and Serica now holds a 40% operatedinterest in the Greater Laggan Area ('GLA'), 10% interest in the Catcher field, 5.21% interest in the Golden Eagle Development ('GEAD'). Further details arein note 16.2 and 16.3. The PUL acquisition consideration, management's assessment of the net assets acquired, liabilities assumed on acquisition and subsequent goodwill arising,were included in Note 29 of the Serica Energy 2025 Annual Report. There have been no changes in the provisional fair value recognised on acquisition. The provisional fair value assets and liabilities identified at acquisition did not include future value that the Group expects to generate from future events in2026 being the completion of the existing SPAs (including synergies). The Group did not own or control the assets and liabilities associated with the existingSPAs as at the 11 December 2025 date of acquisition of PUL as the SPAs were still subject to standard partner and regulatory approvals. Serica did notrecognise deferred tax assets that are contingent on controlling those assets at acquisition. No element of goodwill is expected to be deductible for income taxpurposes and will be reviewed and finalised within 12 months from the acquisition date. The purchase price allocation remains provisional as permitted by IFRS 3. The fair value of identifiable assets and liabilities may be adjusted within themeasurement period of up to one year from the acquisition date for new information which existed at acquisition date and therefore finalised in Serica's fullyear 2026 financial statements. 16.2 Acquisition of Greater Laggan Area (GLA) Interest Overview of the transactionAt the original acquisition date of PUL by Serica Energy plc on 11 December 2025, PUL was party to a separate executed Sale and Purchase Agreement withTotalEnergies. On 26 March 2026, the Group completed the acquisition of a 40% operated interest in the GLA hub in the West of Shetland basin, associatedinfrastructure, together with operated licence interests in four near-field exploration blocks. The assets acquired comprise producing oil and gas interests,associated gas processing and transportation infrastructure, and related operating activities. The acquisition is considered to constitute a business as defined inIFRS 3 Business Combinations and is therefore accounted for as a business combination. The consideration transferred comprised £1 cash consideration, and the Group received net cash proceeds of $55.7 million, reflecting interim post-taxcashflows generated between the Economic Date of 1 January 2024 and the completion date. The acquisition provides Serica with net 2P reserves of 4.0mmboe and net 2C resources of 5.4 mmboe as at 31 December 2025, together with multiple opportunities for future organic growth. Acquisition of GLA - assets acquired and liabilities assumedThe acquisition consideration, management's assessment of the net assets acquired, liabilities assumed on acquisition and subsequent goodwill arising are asfollows: Assets acquired and liabilities assumed at date of acquisition Provisional Fairvaluerecognised onacquisition $000AssetsExploration & Evaluation assets (note 16.5) 20,912Property, plant and equipment (note 16.5) 52,173Net deferred tax asset (note 16.5) 40,056Debtors, prepayments and other assets 205113,346
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LiabilitiesTrade and other payables/other liabilities (2,378)Provisions (note 16.5) (206,177)(208,555) Total identifiable net liabilities at fair value (95,209) Cash consideration received (55,692)Contingent consideration payable 11,400Purchase consideration (44,292) Provisional goodwill on acquisition 50,917 The cash inflow on acquisitions is as follows:Cash consideration received 55,692Net cash inflow on acquisition 55,692 The excess of the purchase consideration over the provisional fair value of the net liabilities assumed was recognised as provisional goodwill at acquisition.The purchase price allocation remains provisional as permitted by IFRS 3. The fair value of identifiable assets and liabilities, and subsequent goodwill, maybe adjusted within the measurement period of up to one year from the acquisition date for new information which existed at acquisition date and thereforefinalised in Serica's full year 2026 financial statements. No element of goodwill is expected to be deductible for income tax purposes. See note 16.4 forfurther information. Contingent consideration payableAs part of the acquisition, the Group may be required to make additional contingent consideration payments based on future value that may be realised fromthe introduction of the Tornado field into the GLA hub. The contingent consideration was measured at fair value of $11.4 million at the acquisition date andrecognised as part of the consideration transferred, reflecting management's estimate of the probability-weighted future payments expected under thearrangement. Subsequent changes in the fair value of the contingent consideration will be recognised in profit or loss. OtherThe Group has not disclosed the pro forma revenue and profit or loss contribution to the combined group as though the acquisition had occurred at thebeginning of the H1 2026 reporting period, as it was impracticable for management to obtain this information for the interim financial statements. 16.3 Acquisition of ONE-Dyas Interests Overview of the transactionAt the original acquisition date of PUL by Serica Energy plc on 11 December 2025, PUL was party to a separate executed Sale and Purchase Agreement withONE-Dyas for the purchase of certain assets for base consideration payable of $6.75 million. The transaction completed on 10 June 2026, and Sericaacquired a 10% interest in the Catcher field and a 5.21% interest in the Golden Eagle Area Development ('GEAD'). Serica received a consideration paymentof $13.0 million, reflecting interim post-tax cashflows between the Economic Date of 1 January 2024 and the date of completion. The non-operated producing interests acquired were in unincorporated joint interests which comprised an integrated set of activities and assets capable ofgenerating outputs and being managed for the purpose of providing goods and generating income. The acquisition is considered to constitute a business asdefined in IFRS 3 Business Combinations and is therefore accounted for as a business combination. Acquisition of ONE-Dyas - assets acquired and liabilities assumedThe acquisition consideration, management's assessment of the net assets, acquired liabilities assumed on acquisition and subsequent goodwill arising are asfollows: Assets acquired and liabilities assumed at date of acquisition Provisional Fair valuerecognised onacquisition $000AssetsProperty, plant and equipment (note 16.5) 4,840Net deferred tax asset (note 16.5) 325Debtors, prepayments and other assets 413Inventory 1,367Underlift receivable 7,90314,848LiabilitiesTrade and other payables (466)Provisions (note 16.5) (65,988)(66,454) Total identifiable net liabilities at fair value (51,606) Cash consideration received (12,990)Purchase consideration (12,990) Provisional goodwill on acquisition 38,616
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The cash inflow on acquisitions is as follows:Cash consideration received 12,990Net cash inflow on acquisition 12,990 The excess of the purchase consideration over the provisional fair value of the net liabilities assumed was recognised as provisional goodwill at acquisition.The purchase price allocation remains provisional as permitted by IFRS 3. The fair value of identifiable assets and liabilities, and subsequent goodwill, maybe adjusted within the measurement period of up to one year from the acquisition date for new information which existed at acquisition date and thereforefinalised in the 12 month period post acquisition. No element of goodwill is expected to be deductible for income tax purposes. See note 16.4 for furtherinformation. OtherIn the 20-day period from the date of acquisition to the period end 30 June 2026, no oil liftings were undertaken and the assets contributed revenue of $niland a loss before tax of $1.0 million to the consolidated group loss before tax from continuing operations of the Group. 16.4. Goodwill The table below reconciles the additions to goodwill arising from the Serica group's PUL, GLA and ONE-Dyas acquisitions, and goodwill expensed in theperiod. $000At 1 January 2025 -Acquisition of Prax Upstream Limited (note 16.1) 56,497 At 31 December 2025 56,497 GLA acquisition (note 16.2) 50,917ONE-Dyas acquisition (note 16.3) 38,616Goodwill recognised during the period 89,533Less:Expense of goodwill during the period (95,582) At 30 June 2026 50,448 Goodwill recognised during the periodIn addition to goodwill that existed at 31 December 2025 following Serica's acquisition of PUL, further goodwill arose during H1 2026 on the acquisitions ofthe GLA and ONE-Dyas interests. The goodwill provisionally recognised arose from two principal components: from the requirements to recognise deferredtax on the difference between the fair value and the tax base of the assets acquired; and the value of future economic benefits expected to be realised from theacquired assets and operations, that did not qualify for separate recognition under IFRS 3, including the potential to utilise tax losses that arose on the widerPrax Upstream Limited acquisition. None of the goodwill recognised is expected to be deductible for income tax purposes. Goodwill subsequently expensed during the periodFollowing the completion of acquisitions in H1 2026, value attributed to tax losses was reflected as deferred tax assets in the reporting period. The incomestatement deferred tax credit for the period of $141.6 million included amounts recognised in respect of PUL deferred tax assets. The value attributed to thePUL sub-group effectively assumed some of the value of goodwill initially recognised and noted above. This led to the expense of $95.6 million in goodwillnoted in the table above. The goodwill balance as at 30 June 2026 primarily arises from the requirements to recognise deferred tax on the difference between the fair value and the taxbase of the assets acquired. This fair value uplift is not tax deductible and therefore results in a net deferred tax liability and corresponding entry to goodwill. 16.5 Reconciliation of assets acquired and liabilities assumed The table below reconciles the assets acquired and liabilities assumed as part of the acquisition to the corresponding line items disclosed elsewhere in thesefinancial statements. This reconciliation is provided to facilitate an understanding of how the acquired balances have been allocated and presented within theGroup's statement of financial position and the related note disclosures. GLA acquisition(note 16.2) ONE-Dyasacquisition (note16.3) Total As presented in the financial statements: $'000 $'000 $'000 Exploration and evaluation assets (note 9) 20,912 - 20,912 Property, plant, and equipment (note 10) 52,173 4,840 57,013 Provisions (note 11) 206,177 65,988 272,165 Deferred tax (note 13) 40,056 325 40,381 Business combination, net cashreceived/acquired (statement of cash flow) 55,692 12,990 68,682 17. Subsequent events RBL refinancingOn 23 July 2026 the Group announced that it had completed a new six-year senior secured Reserve Based Lending (RBL) facility (see note 12). Recommended acquisition of Pharos EnergyOn 26 July, the Group announced the potential acquisition of Pharos Energy plc which is complementary to the Group's long-term strategy and expected toenhance portfolio diversification and growth. Completion of the transaction is subject to ongoing approval. 18. Publication of Non-Statutory AccountsThe financial information contained in this interim statement does not constitute statutory accounts as defined in the Companies Act 2006. The financialinformation for the full preceding year is based on the statutory accounts for the financial year ended 31 December 2025, which are available at theCompany's registered office at 72 Welbeck Street, London W1G 0AY and on its website at www.serica-energy.com and on SEDAR at www.sedar.com.
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This interim statement will be made available at the Company's registered office at 72 Welbeck Street, London W1G 0AY and on its website at www.serica-energy.com and on SEDAR at www.sedar.com. Reconciliation of non-IFRS measures Serica uses certain measures of performance that are not specifically defined under IFRS or other generally accepted accounting principles ('GAAP'). Thesenon-IFRS measures, which are presented within the financial review, are defined below: EBITDAX: Earnings before interest, tax, depreciation and amortisation, impairments, transaction costs, unrealised hedging expenses, FX translation effects,asset revaluation effects, other noncash gains or expenses and exploration expenditure. This is a useful indicator of underlying business performance and thedefinition adopted by Serica is consistent with that stipulated in the Group's reserve based lending ('RBL') facility. A reconciliation from Operating(Loss)/Profit to EBITDAX is provided below: $ 000 H1 2026 H1 2025 Operating (Loss)/Profit (49,781) 118,087 Add back transaction costs 3,048 -Add back DD&A 130,630 54,932Add back depreciation in G&A 644 515 Add back E&E expenses and licence costs - 1,196Add back impairment of producing assets 5,820 -Deduct contract revenue - other - (5,408) Add back / (deduct) unrealised hedging 110,843 (53,136)Add back goodwill expense 95,582 -Add back / (deduct) FX effects/remeasurements 2,116 635 Add back share-based payments 1,648 1,673 EBITDAX 300,550 118,494 Capital Expenditure: Comprises the cash spend (prior to tax allowances) on the acquisition of PP&E assets and the purchase of exploration and appraisalassets. Depicts how much the Group has spent, on a cash basis, on purchasing fixed assets in order to further its business goals and objectives. It is a usefulindicator of the Group's organic expenditure on oil and gas assets, and exploration and appraisal assets, incurred during a period on a pre-tax basis. $ 000 H1 2026 H1 2025 Purchase of PP&E assets 79,427 136,527Purchase of E&E assets 1,370 1,179 Capital Expenditure 80,797 137,706 Post-tax CFFO: comprises cash inflow from operations adjusted by the cash tax paid or received for the period. Serica considers that this is a useful measureof the cash generation of the business prior to the decisions made by the Group in relation to capital allocation and utilises this measure as the basis fordetermining its dividend in line with its dividend policy. $ 000 H1 2026 H1 2025 Cash inflow from operations 270,493 101,954Add taxation received / (paid) 9,126 70,554 Post-tax CFFO 279,619 172,508 Free cash flow: net cash flow from operating activities less cash used in investing activities (excluding acquisition costs) and financing activities. Thismeasure is considered a useful indicator of the Group's ability to invest, repay the Group's debt and meet other payment obligations. Group free cash flowreconciles to net cash flow from operating activities as follows $ 000 H1 2026 H1 2025 Net cash flow from operating activities 273,772 172,404 Net cash flow from investing activities (14,828) (145,649) Net cash flow from financing activities 48,767 (12,421)Adjustedby: Repayment of loans and borrowings 231,000 - Proceeds from borrowings net of fees (293,199) 979 Payments for share buyback - - Proceeds from issue of shares - (178) Acquisition and transactions receipts (net) (61,466) 10,416 Free cash flow 184,046 25,551 Adjusted net cash / (debt): Total cash and cash equivalents plus the level of interest bearing loans net of the carrying value of unamortised fees. This is anindicator of the Group's indebtedness and contribution to capital structure. $ 000 30 June 2026 31 December2025Interest bearing loans (284,139) (221,488) Add back unamortised fees (15,861) (9,512)
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Cash and cash equivalents 324,451 18,840 Restricted cash 1,460 12,060 Adjusted Net Cash/(Debt) 25,911 (200,100)