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(1)   Non-IFRS financial measure or non-IFRS ratio – see “Non-IFRS Financial Measures and Ratios” section below.

Financial and Operating Results Summary

(1)   Working interest share production before royalties.
(2)   Non-IFRS financial measure or non-IFRS ratio – see “Non-IFRS Financial Measures and Ratios” section below.
(3)   Includes restricted cash of US$23.4 million.

Financial Update

The Company’s Q1 2025 financial performance reflects ongoing strong production operations at all four of its fields in the offshore Gulf of Thailand. Valeura’s working interest share production before royalties totalled 2.15 million bbls during Q1 2025, an increase of 8% from Q1 2024. Production was in line with the Company’s expectations considering the Nong Yao field experienced a planned maintenance shutdown.

Oil sales totalled 1.88 million bbls during Q1 2025, which was less than the volume produced, and therefore contributed to an oil inventory increase to 0.89 million bbls at March 31, 2025. As all of the Company’s oil production is stored in floating offshore vessels before being sold in parcels of approximately 200,000 – 300,000 bbls, at any given time, the Company maintains some quantity of oil held in inventory.

Price realisations averaged US$78.7/bbl, which was 7% lower than the same period in 2024, reflecting lower global benchmark oil prices. The Company’s oil sales continue to achieve a premium when compared to the Brent crude oil benchmark, averaging US$2.9/bbl in Q1 2025, versus US$1.6/bbl in Q1 of 2024. Valeura generated oil revenue of US$148 million in Q1 2025, essentially unchanged from the oil revenue generated Q1 2024, reflecting the increase in production being offset by reduced sales prices.

Operating expenses during Q1 2025 reflect a long-term trend of improving production efficiency, influenced by ongoing strong performance of the Nong Yao field, which is both the Company’s largest source of production and also the lowest unit cost field in Valeura’s portfolio. Along with operating expenses, the Company includes the price of leases for its floating offshore infrastructure (being US$8.5 million) to derive an Adjusted Opex⁽¹⁾ of US$51.7 million in Q1 2025, which equates to a per-unit rate of US$24.1/bbl, an improvement of 8% when compared to Q1 2024.

Valeura generated adjusted cashflow from operations⁽¹⁾ (pre-tax) of US$74.0 million, which was a 55% increase over Q1 2024. The increase is directly related to the more tax-efficient corporate structure as a result of the Company’s corporate re-organisation, which was completed in November 2024. Under the new structure, Valeura may apply its tax loss carry-forwards to taxable income for the Nong Yao, Manora, and Wassana fields.

While cash tax payments are normally paid in May and August each year, the Company made a final tax payment of US$39.2 million in connection with its corporate restructuring. This payment effectively completed the tax obligations for its Thai III licences under their previous organisation structure, giving rise to the more optimised application of tax loss carry-forwards as noted above. In addition to this out-of-round payment, Valeura made cash outlays in respect of its operating costs and capex of US$32.9 million. As a result, Valeura’s cash position at March 31, 2025 was US$238.9 million, inclusive of restricted cash of US$23.4 million. Valeura’s net working capital surplus was US$253.5 million at March 31, 2025.

(1)   Non-IFRS financial measure or non-IFRS ratio – see “Non-IFRS Financial Measures and Ratios” section below.

Operations Update and Outlook

During Q1 2025, Valeura had ongoing production operations at all of its Gulf of Thailand fields, including Jasmine, Manora, Nong Yao, and Wassana fields. Total working interest share production before royalties averaged 23,853 bbls/d, which was in line with management’s expectations and consistent with achieving the Company’s guidance range for the full year 2025 of 23,000 – 25,500 bbls/d. One drilling rig was under contract throughout the quarter.

Jasmine/Ban Yen

Oil production before royalties from the Jasmine/Ban Yen field, in Licence B5/27 (100% operated interest) averaged 8,356 bbls/d during Q1 2025.

In February 2025, the Company’s contracted drilling rig began a seven-well infill drilling campaign which includes both development and appraisal targets on the Jasmine C, Jasmine D, and Ban Yen A facilities. Drilling operations are progressing safely and on time. The drilling programme is expected to be complete approximately by the end of May 2025.

Also during Q1 2025, a low-BTU gas generator was delivered to the Jasmine B platform. Installation and commissioning activities in respect of the low-BTU gas generator are underway, with the new equipment planned to be fully operational and online later in Q2 2025. The low-BTU gas generator is a modernisation of the Jasmine B platform’s power generation facility, which will enable a waste gas stream to be used as feedstock for power generation, thereby reducing the Jasmine field’s reliance on diesel. As a result, Valeura anticipates immediate savings in operating expenses and a long-term reduction in its greenhouse gas emissions from the Jasmine field.

Nong Yao

At the Nong Yao field, in Licence G11/48 (90% operated working interest), Valeura’s working interest share production before royalties averaged 9,275 bbls/d. As a result of the Company’s development of the Nong Yao C field extension in 2024, Nong Yao has become the Company’s largest source of production, with the Company’s lowest per unit Adjusted Opex.

Near the end of Q1 2025, Valeura conducted a planned seven-day annual maintenance shutdown of the Nong Yao field. All maintenance work was performed safely, under budget, and ahead of schedule. The Nong Yao field has since resumed normal operations.

Wassana

Oil production before royalties from the Wassana field, in Licence G10/48 (100% operated interest), averaged 3,686 bbls/d during Q1 2025. Production operations progressed without incident throughout the quarter. No wells were drilled during the quarter.

During Q1 2025 Valeura completed the front end engineering and design work for the potential redevelopment of the Wasssana field and more recently has finalised detailed contracting and procurement work to validate cost assumptions for the project.

As announced separately today, the Company has determined a positive final investment decision and intends to pursue the Wassana field redevelopment project, targeting the start of production from a newly built facility in Q2 2027.

Manora

At the Manora field, in Licence G1/48 (70% operated working interest), Valeura’s working interest share of oil production before royalties averaged 2,536 bbls/d.

During Q1 2025, Valeura completed a five-well infill drilling campaign on the Manora field, comprised of both development and appraisal targets. The drilling programme achieved its objectives and successful appraisal results have identified between three and five potential future drilling targets, which are now being evaluated for inclusion in a future drilling programme.

Türkiye

The Company had no active operations in Türkiye during Q1 2025. Valeura continues to hold an interest in a potentially large deep gas play in the Thrace basin in the northwest part of the country. The terms of the subject leases and licences have been extended to June 27, 2026, with further extensions possible for appraisal purposes thereafter.

Valeura intends to farm out a portion of its interest to a new partner in order to jointly pursue the next phase of appraisal work. The Company continues to see the Thrace basin deep gas play as a source of significant potential value in the longer-term.

Webcast

Valeura’s Annual General Meeting of Shareholders is scheduled for today, May 14, 2025, at 4:00 P.M. (Calgary time) in Calgary. Shareholders may attend in person, as further detailed in the Management’s Information Circular which was mailed to shareholders and is available on the Company’s website and on www.sedarplus.ca. A webcast of the live event is available with the link below. In addition to the meeting, Valeura’s management will discuss the Q1 2025 results and will host a question and answer session. Written questions may be submitted through the webcast system or by email to IR@valeuraenergy.com.

Participants are advised to register for the online event in advance, using the following link: https://events.teams.microsoft.com/event/f0e30b40-c6bc-4673-bd84-b57491e1ba58@a196a1a0-4579-4a0c-b3a3-855f4db8f64b

An audio only feed of the Meeting is available by phone using the Conference ID and dial-in numbers below:

Conference ID: 239 311 896 799

Dial-in numbers:

Canada: (833) 845-9589,,49176158#
Singapore: +65 6450 6302,,49176158#
Thailand: +66 2 026 9035,,49176158#
Türkiye: 0800 142 034779,,49176158#
United Kingdom: 0800 640 3933,,49176158#
United States: (833) 846-5630,,49176158#

For further information, please contact:

Contact details for the Company’s advisors, covering research analysts and joint brokers, including Auctus Advisors LLP, Canaccord Genuity Ltd (UK), Cormark Securities Inc., Research Capital Corporation, and Stifel Nicolaus Europe Limited, are listed on the Company’s website at www.valeuraenergy.com/investor-information/analysts/.

About the Company

Valeura Energy Inc. is a Canadian public company engaged in the exploration, development and production of petroleum and natural gas in Thailand and in Türkiye. The Company is pursuing a growth-oriented strategy and intends to re-invest into its producing asset portfolio and to deploy resources toward further organic and inorganic growth in Southeast Asia. Valeura aspires toward value accretive growth for stakeholders while adhering to high standards of environmental, social and governance responsibility.

Additional information relating to Valeura is also available on SEDAR+ at www.sedarplus.ca.

Non-IFRS Financial Measures and Ratios

This news release includes references to financial measures commonly used in the oil and gas industry such as adjusted EBITDAX, net working capital, adjusted net working capital, adjusted cashflow from operations, adjusted opex, adjusted capex, net cash and outstanding debt which are not generally accepted accounting measures under International Financial Reporting Standards (“IFRS Accounting Standards”) which are not generally accepted accounting measures under IFRS Accounting Standards as issued by International Accounting Standards Board (“IASB”) and do not have any standardised meaning prescribed by IFRS Accounting Standards and, therefore, may not be comparable with similar definitions that may be used by other public companies. Management believes that adjusted EBITDAX, net working capital, adjusted net working capital, adjusted cashflow from operations, adjusted opex, adjusted capex, net cash and outstanding debt are useful supplemental measures that may assist shareholders and investors in assessing the financial performance and position of the Company. Non-IFRS financial measures should not be considered in isolation or as a substitute for measures prepared in accordance with IFRS Accounting Standards.

Adjusted EBITDAX: is a non-IFRS financial measure which does not have a standardised meaning prescribed by IFRS Accounting Standards. This non-IFRS financial measure is included because management uses the information to analyse the financial performance of the Company. Adjusted EBITDAX is a non-IFRS and non-standardised variant of EBITDAX, adjusted to remove non-cash items as well as certain non-recurring costs including severance payments and other one-off items in relation to the Company’s recent acquisitions. Adjusted EBITDAX is calculated by adjusting profit for the year before other items as reported under IFRS Accounting Standards to exclude the effects of other income, exploration, SRB, finance income and expense, depletion, depreciation & amortisation (“DD&A”), other costs, and certain non-cash items (such as impairments, foreign exchange, unrealised risk management contracts, reassessment of contingent consideration and gains or losses arising from the disposal of capital assets). In addition, other unusual or non-recurring items are excluded from Adjusted EBITDAX, as they are not indicative of the underlying financial performance of the Company.

(1)     Items are not shown in the Interim Financial Statements.
(2)    Represents non-recurring costs associated with share-based compensation, actual severance incurred - See “General and Administrative ("G&A") Expenses” for more details.

Adjusted opex and adjusted opex per bbl: are a non-IFRS financial measure and a non-IFRS financial ratio, respectively, which do not have standardised meanings prescribed by IFRS Accounting Standards. This non-IFRS financial measure and ratio are included because management uses the information to analyse cash generation and financial performance of the Company. Operating cost represents the operating cash expenses incurred by the Company during the period including the leases that are associated with operations, such as bareboat contracts for key operating equipment, such as FSOs, FPSOs, MOPU, and warehouses. Adjusted opex is calculated by effectively adjusting non-cash items from the operating cost and adding lease costs.

Adjusted opex is divided by production in the period to arrive at adjusted opex per bbl. Valeura calculates adjusted opex per barrel, to provide a more consistent indication of the cost of field operations. Adjusted opex, as opposed to operating expenses, excludes the impacts of non-recurring, non-cash items such as prior period adjustments, and adds back lease costs in relation to FSOs, FPSOs, MOPU, and other facilities.

(1)    Represent write down inventory to net realisable value.
(2)   The item is not shown in the Interim Financial Statements. The cost of crude inventory is capitalised from operating costs. As a result, the Company has excluded the effect of crude inventory capitalization.
(3)   In accordance with IFRS 16 - Leases, the Company recognised cost related to its operating leases – attributed to FSO and FPSO vessels, MOPU used at its Jasmine/Ban Yen, Nong Yao, Manora and Wassana fields, as well as onshore warehouse facilities costs to its balance sheet and finance cost in the profit and loss statement. In order to report a more relevant lifting cost, the Company has included costs associated with these leases in the adjusted operating cost calculation. This will be a recurring adjustment.

Adjusted cashflow from operations and adjusted cashflow from operations per barrel: are a non-IFRS financial measure and a non-IFRS financial ratio, respectively, which do not have a standardised meaning prescribed by IFRS Accounting Standards. This non-IFRS finance measure and ratio are included because management uses the information to analyse cash generation and financial performance of the Company. Adjusted cashflow from operations is calculated using two methods which generate the same figures: a) by subtracting from oil revenues, adjusted opex, royalties, general and administrative costs which are adjusted for non-recurring charges (generating the adjusted pre-tax cashflow), and accrued PITA taxes and SRB expenses, and b) to enhance and facilitate to the reader a reconciliation of this non-IFRS measure, the Company also presented the adjusted cash flow from operations by calculating from cash generated from (used in) operating activities in the consolidated statement of cash flows, adjusting with non-cash items, adjusted opex, general and administrative costs which are adjusted for non-recurring charges (generating the adjusted pre-tax cashflow), and accrued PITA tax and SRB expenses.

Adjusted cashflow from operations is divided by production in the period to arrive at adjusted cashflow from operations per bbl. Valeura calculates Adjusted cashflow from operations per barrel, to provide a more consistent indication of cashflow generated from operations by the Company.

Outstanding debt and net cash: are non-IFRS financial measures which do not have a standardised meaning prescribed by IFRS Accounting Standards. These non-IRFS financial measures are provided because management uses the information to a) analyse financial strength and b) manage the capital structure of the Company. These non-IFRS measures are used to ensure capital is managed effectively in order to support the Company’s ongoing operations and needs.

Net working capital and adjusted net working capital: are non-IFRS financial measures which do not have a standardised meaning prescribed by IFRS Accounting Standards. These non-IFRS financial measures are included because management uses the information to analyse liquidity and financial strength of the Company. Net working capital is calculated by deducting current liabilities from current assets. Adjusted net working capital is calculated by adding back the current leases liabilities and including non-current restricted cash in net working capital.

The leases are associated with operations, such as bareboat contracts for key operating equipment, such as FSOs, FPSOs, MOPU, and warehouses which are included in the Company’s disclosed adjusted opex (and adjusted opex guidance). Management believes the adjusted net working capital provides a useful data point to the reader to ascertain the business’ next-twelve-months surplus or deficit capital requirement. It is also a data point that management uses for cash management.

Adjusted capex: is a non-IFRS measure which does not have a standardised meaning prescribed by IFRS Accounting Standards. Adjusted capex is defined as the addition in capital expenditure for drilling, brownfield, and other PP&E. Management uses this non-IFRS measure to analyse the capital spending of the Company and assess investments in its assets.

Advisory and Caution Regarding Forward-Looking Information

Certain information included in this news release constitutes forward-looking information under applicable securities legislation. Such forward-looking information is for the purpose of explaining management’s current expectations and plans relating to the future. Readers are cautioned that reliance on such information may not be appropriate for other purposes, such as making investment decisions. Forward-looking information typically contains statements with words such as “anticipate”, “believe”, “expect”, “plan”, “intend”, “estimate”, “propose”, “project”, “target” or similar words suggesting future outcomes or statements regarding an outlook.

Forward-looking information in this news release includes, but is not limited to, the ability to optimise use of tax loss carry-forwards; the Company’s ability to weather volatile markets better than many of its competitors; the Company being in a prime position to pursue its growth ambitions; the Company’s expectations about meeting it’s guidance range for the full year 2025; timing to complete the Jasmine field drilling programme; timing for the Jasmine low-BTU gas generator to be fully operational and online and the potential for savings in operating expenses and reduced greenhouse gas emissions thereafter; timing for the Wassana redevelopment project and start of production from a newly built facility; expectations for future drilling on the Manora field; and the potential for further extensions of the Thrace basin leases and licences.

Although the Company believes the expectations and assumptions reflected in such forward-looking information are reasonable, they may prove to be incorrect.

Forward-looking information is based on management’s current expectations and assumptions regarding, among other things: political stability of the areas in which the Company is operating; continued safety of operations and ability to proceed in a timely manner; continued operations of and approvals forthcoming from governments and regulators in a manner consistent with past conduct; ability to achieve extensions to licences in Thailand and Türkiye to support attractive development and resource recovery; future drilling activity on the required/expected timelines; the prospectivity of the Company’s lands; the continued favourable pricing and operating netbacks across its business; future production rates and associated operating netbacks and cash flow; decline rates; future sources of funding; future economic conditions; the impact of inflation of future costs; future currency exchange rates; interest rates; the ability to meet drilling deadlines and fulfil commitments under licences and leases; future commodity prices; the impact of the Russian invasion of Ukraine; the impact of conflicts in the Middle East; royalty rates and taxes; management’s estimate of cumulative tax losses being correct; future capital and other expenditures; the success obtained in drilling new wells and working over existing wellbores; the performance of wells and facilities; the availability of the required capital to funds its exploration, development and other operations, and the ability of the Company to meet its commitments and financial obligations; the ability of the Company to secure adequate processing, transportation, fractionation and storage capacity on acceptable terms; the capacity and reliability of facilities; the application of regulatory requirements respecting abandonment and reclamation; the recoverability of the Company’s reserves and contingent resources; future growth; the sufficiency of budgeted capital expenditures in carrying out planned activities; the impact of increasing competition; the availability and identification of mergers and acquisition opportunities; the ability to successfully negotiate and complete any mergers and acquisition opportunities; the ability to efficiently integrate assets and employees acquired through acquisitions; global energy policies going forward; international trade policies; future debt levels; and the Company’s continued ability to obtain and retain qualified staff and equipment in a timely and cost efficient manner. In addition, the Company’s work programmes and budgets are in part based upon expected agreement among joint venture partners and associated exploration, development and marketing plans and anticipated costs and sales prices, which are subject to change based on, among other things, the actual results of drilling and related activity, availability of drilling, offshore storage and offloading facilities and other specialised oilfield equipment and service providers, changes in partners’ plans and unexpected delays and changes in market conditions. Although the Company believes the expectations and assumptions reflected in such forward-looking information are reasonable, they may prove to be incorrect.

Forward-looking information involves significant known and unknown risks and uncertainties. Exploration, appraisal, and development of oil and natural gas reserves and resources are speculative activities and involve a degree of risk. A number of factors could cause actual results to differ materially from those anticipated by the Company including, but not limited to: the ability of management to execute its business plan or realise anticipated benefits from acquisitions; the risk of disruptions from public health emergencies and/or pandemics; competition for specialised equipment and human resources; the Company’s ability to manage growth; the Company’s ability to manage the costs related to inflation; disruption in supply chains; the risk of currency fluctuations; changes in interest rates, oil and gas prices and netbacks; the risk that the Company’s tax advisors’ and/or auditors’ assessment of the Company’s cumulative tax losses varies significantly from management’s expectations of the same; potential changes in joint venture partner strategies and participation in work programmes; uncertainty regarding the contemplated timelines and costs for work programme execution; the risks of disruption to operations and access to worksites; potential changes in laws and regulations, including international treaties and trade policies; the uncertainty regarding government and other approvals; counterparty risk; the risk that financing may not be available; risks associated with weather delays and natural disasters; and the risk associated with international activity. See the most recent annual information form and management’s discussion and analysis of the Company for a detailed discussion of the risk factors.

Certain forward-looking information in this news release may also constitute “financial outlook” within the meaning of applicable securities legislation. Financial outlook involves statements about Valeura’s prospective financial performance or position and is based on and subject to the assumptions and risk factors described above in respect of forward-looking information generally as well as any other specific assumptions and risk factors in relation to such financial outlook noted in this news release. Such assumptions are based on management’s assessment of the relevant information currently available, and any financial outlook included in this news release is made as of the date hereof and provided for the purpose of helping readers understand Valeura’s current expectations and plans for the future. Readers are cautioned that reliance on any financial outlook may not be appropriate for other purposes or in other circumstances and that the risk factors described above or other factors may cause actual results to differ materially from any financial outlook.

The forward-looking information contained in this news release is made as of the date hereof and the Company undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, unless required by applicable securities laws. The forward-looking information contained in this news release is expressly qualified by this cautionary statement.

This news release does not constitute an offer to sell or the solicitation of an offer to buy securities in any jurisdiction, including where such offer would be unlawful. This news release is not for distribution or release, directly or indirectly, in or into the United States, Ireland, the Republic of South Africa or Japan or any other jurisdiction in which its publication or distribution would be unlawful.

Neither the Toronto Stock Exchange nor its Regulation Services Provider (as that term is defined in the policies of the Toronto Stock Exchange) accepts responsibility for the adequacy or accuracy of this news release.

This information is provided by Reach, the non-regulatory press release distribution service of RNS, part of the London Stock Exchange. Terms and conditions relating to the use and distribution of this information may apply. For further information, please contact rns@lseg.com or visit www.rns.com.