CALGARY, AB / ACCESS Newswire / February 10, 2026 / Valeura Energy Inc. (TSX:VLE,OTC:VLERF)(OTCQX:VLERF) (‘Valeura’ or the ‘Company’) announces record high proved plus probable (‘2P’) reserves, an increase in its 2P reserves life index (‘RLI’), and a third consecutive year of approximately 200% 2P reserves replacement ratio.

Highlights

• Record high proved (‘1P’) reserves of 37.9 MMbbls, proved plus probable (‘2P’) reserves of 57.8 MMbbls, and proved plus probable plus possible (‘3P’) reserves of 71.2 MMbbls;

• Adding, not just replacing reserves, with a 2P reserves replacement ratio of 192%;

• 2P reserves net present value (‘NPV ₁₀ ‘) before tax of US$872 million and US$692 million on an after tax basis ⁽¹⁾ ;

• Year-end 2025 cash position of US$306 million, and a net asset value (‘NAV’) of US$998 million, equating to approximately C$13 per common share ⁽²⁾ ;

• RLI increased to a new record of 7.5 years, on a 2P basis ⁽³⁾ ; and

• Above volumes and values do not include the recent farm-in to blocks G1/65 and G3/65 in the Gulf of Thailand, which will be additive upon completion ⁽⁴⁾ (the ‘Farm-in Transaction’).

(1) Discounted at 10% (‘NPV ₁₀ ‘)
(2) 2P NPV ₁₀ after tax plus cash of US$305.7 million (no debt), using US$/C$ exchange rate of 1.3722 and 105.5 million common shares of the Company (the ‘Common Shares’) outstanding, as at 31 December 2025
(3) Based on 2P reserves divided by the mid-point of the Company’s 2026 guidance production of 21 Mbbls/d
(4) Subject to government approval

Dr. Sean Guest, President and CEO commented:

‘For the third time in a row we have added approximately double the reserves we produced during the year, achieving a 2P reserves replacement ratio of 192%. This outcome is especially strong given the sharp drop in oil prices in 2025, meaning our reserves were evaluated at a forward price much lower than in the prior year.

We are committed to seeing through the volatility in the global commodity market and have maintained our focus on adding to the ultimate potential and longevity of our portfolio. This is reflected in an improvement to our RLI, which is now at a new record high of 7.5 years (based on 2P reserves and anticipated 2026 production). Our RLI has increased steadily over the three years we have been operating in Thailand, and we see this as affirmation of our ability to add more years of future cash flow, for the benefit of all stakeholders.

The net asset value of our business, defined as year-end cash plus our 2P net revenue (NPV ₁₀ ), is US$1 billion which equates to approximately C$13/Common Share.

We are mindful of the concept of portfolio renewal and therefore continue to focus on contingent resources as well, which provides the feedstock for future reserves additions. We believe our decision to redevelop the Wassana field is an excellent example of this progression. At the same time, we have added more volumes through life-extending work with our Jasmine licence and through ongoing drilling success across the portfolio. In addition, upon completion of our strategic Farm-in Transaction to blocks G1/65 and G3/65 in the Gulf of Thailand, these new volumes will be additive to the volumes we have reported today.

We believe our year-end 2025 reserves and resources demonstrate our ability to drive deeper and longer-lived value from our assets, even when faced with a correction in commodity prices. I believe this underscores both the robustness of our portfolio and the relentless commitment to value shared by our world class team.’

Independent Reserves and Resources Evaluation

Valeura commissioned Netherland, Sewell & Associates, Inc. (‘NSAI’) to assess reserves and resources for all of its Thailand assets as of 31 December 2025. NSAI’s evaluation is presented in a report dated 09 February 2026 (the ‘NSAI 2025 Report’). This follows previous evaluations conducted by NSAI for the previous three years ended 31 December 2024 (the ‘NSAI 2024 Report’), 31 December 2023 (the ‘NSAI 2023 Report’), and 31 December 2022.

NSAI 2025 Report: Oil and Gas Reserves by Field Based on Forecast Prices and Costs

Summary of Reserves Replacement, Value, and Field Life

Valeura added volumes within the 1P, 2P, and 3P categories in 2025. As compared to the NSAI 2024 Report, the NSAI 2025 Report indicates an increase of 5.6 MMbbls of proved (1P) reserves and 7.8 MMbbls of proved plus probable (2P) reserves, after having produced 8.5 MMbbls of oil in 2025. This implies a 1P reserves replacement ratio of 166% and a 2P reserves replacement ratio of 192%. 2025 was the Company’s third consecutive year of recording new reserves additions well in excess of volumes produced. The Company’s reserves replacement ratio on a 2P basis was 245% in 2024 and 218% in 2023.

Valeura’s RLI has increased for a third year in a row. Based on the mid-point of the Company’s 2026 production guidance of 19.5 – 22.5 Mbbls/d (21.0 Mbbls/d), on a 2P reserves basis as of 31 December 2025, the Company estimates its RLI to be approximately 7.5 years. This represents an increase from the Company’s RLI of 5.6 years as at 31 December 2024 and 4.5 years as at 31 December 2023 (calculated on the same basis).

While the 2025 2P reserves increased relative to 2024, the revenue and NPV ₁₀ associated with these reserves is slightly lower than 2024. This reduction in value is driven by the significant drop in benchmark oil prices in 2025, causing NSAI to use a much lower oil price forecast in their year-end 2025 evaluation. The Company estimates that, based on the 2P net present value of estimated future revenue after income taxes in the NSAI 2025 Report (based on a 10% discount rate), plus the Company’s 2025 year-end cash position of US$305.7 million, the Company has a 2P NAV of US$997.7 million. Using the year-end count of Common Shares outstanding (being 105,535,429 Common Shares) and 31 December 2025 foreign currency exchange rates (which reflects a stronger Canadian dollar), Valeura’s NAV equates to approximately C$13/Common Share.

(1) Cash at 31 December 2025 of US$305.7 million
(2) Issued and outstanding Common Shares as at 31 December 2025
(3) US$/C$ exchange rate of 1.3722 at 31 December 2025

The NSAI 2025 Report indicates a further extension in the anticipated end of field life for the Jasmine, Wassana and Manora fields, and a slight reduction in the anticipated end of field life for the Nong Yao field.

2P reserves by field, and their associated after-tax 2P NPV ₁₀ values are indicated below. The year-on-year change between the NSAI 2024 Report and NSAI 2025 Report indicates an increase in both 2P reserves volumes and the associated after-tax value for both the Jasmine and Wassana fields, reflecting the conversion of 2C resources to 2P reserves in both instances, bolstered in particular by the Company’s decision to proceed with redevelopment of the Wassana field, for which the final investment decision was announced in May 2025.

Reserves volumes and associated after-tax 2P values for the Manora and Nong Yao fields have decreased between the NSAI 2024 Report and NSAI 2025 Report, driven primarily by the significantly reduced forecast oil pricing applied in the year-end 2025 evaluation vs the year-end 2024 evaluation. In the case of Nong Yao, the year-on-year decline in NPV ₁₀ is also influenced by the valuation ‘roll-forward’ effect: following the field’s expansion in 2024, Nong Yao delivered strong production in 2025, effectively bringing forward and monetising a meaningful portion of the value previously reflected in NSAI 2024 Report. This value realisation was partially offset by reserves replacement at Nong Yao, with NSAI reporting additions during 2025 that helped replenish the reserve base and support ongoing field life.

Near-term forecast oil prices in the NSAI 2025 Report are 19% lower than in the NSAI 2024 Report. The Brent crude oil reference prices used in estimating the future net revenue from oil reserves have been revised downward in accordance with the Canadian Oil and Gas Evaluation Handbook requirements, which mandates the use of forward curve prices in near-term forecasts.

Net present values of future net revenue from oil reserves are based on cost estimates as of the date of the NSAI 2025 Report, and the forecast Brent crude oil reference prices as indicated above. Specific price forecasts for each of the Company’s fields are adjusted for oil quality and market differentials, as guided by actual recent price realisations for each of the fields’ crude oil sales.

All estimated costs associated with the eventual decommissioning of the Company’s fields are included as part of the calculation of future net revenue. As in previous years, this can result in a negative future net revenue estimate for the 1P Proved Producing Developed category as these most conservative volumes are encumbered with the entire decommissioning cost for the field.

Contingent Resources

NSAI assessed the Company’s contingent resources of its Thailand assets for additional reservoir accumulations and reported estimates in the NSAI 2025 Report, as it has done in each of the preceding three years. Contingent resources are heavy crude oil and light/medium crude oil, and are further divided into three subcategories, being Development Unclarified, Development Not Viable, and Development on Hold (see oil and gas advisories). Each subcategory is assigned a percentage risk, reflecting the estimated chance of development. Aggregate totals are provided below.

During 2025, Valeura successfully converted a substantial portion of its Best Estimate (2C) Contingent Resources to Reserves.

The above Contingent Resources do not include any resources from the Farm-in Transaction, where Valeura expects to earn a 40% non-operated working interest in Gulf of Thailand blocks G1/65 and G3/65. The Farm-in Transaction is subject to government approval, which is anticipated in due course, following completion of Thailand’s general election.

Further Disclosure

Valeura intends to disclose a summary of the NSAI 2025 Report to Thailand’s upstream regulator later in February 2025. Thereafter, the Company will publish its estimates of reserves and resources in accordance with the requirements of National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities along with its annual information form for the year ended 31 December 2025, in March 2026.

For further information, please contact:

Valeura Energy Inc. (General Corporate Enquiries) +65 6373 6940
Sean Guest, President and CEO
Yacine Ben-Meriem, CFO
Contact@valeuraenergy.com

Valeura Energy Inc. (Investor and Media Enquiries) +1 403 975 6752 / +44 7392 940495
Robin James Martin, Vice President, Communications and Investor Relations
IR@valeuraenergy.com

Contact details for the Company’s advisors, covering research analysts and joint brokers, including Auctus Advisors LLP, Beacon Securities Limited, Canaccord Genuity Ltd (UK), Cormark Securities Inc., Research Capital Corporation, Roth Canada Inc., 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.

Oil and Gas Advisories

Reserves and contingent resources disclosed in this news release are based on an independent evaluation

conducted by the incumbent independent petroleum engineering firm, NSAI with an effective date of 31 December 2025. The NSAI estimates of reserves and resources were prepared using guidelines outlined in the Canadian Oil and Gas Evaluation Handbook and in accordance with National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities . The reserves and contingent resources estimates disclosed in this news release are estimates only and there is no guarantee that the estimated reserves and contingent resources will be recovered.

This news release contains a number of oil and gas metrics, including ‘NAV’, ‘reserves replacement ratio’, ‘RLI’, and ‘end of field life’ which do not have standardised meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies. Such metrics are commonly used in the oil and gas industry and have been included herein to provide readers with additional measures to evaluate the Company’s performance; however, such measures are not reliable indicators of the future performance of the Company and future performance may not compare to the performance in previous periods.

‘NAV’ is calculated by adding the estimated future net revenues based on a 10% discount rate to net cash, (which is comprised of cash less debt) as of 31 December 2025. NAV is expressed on a per share basis by dividing the total by basic Common Shares outstanding. NAV per share is not predictive and may not be reflective of current or future market prices for Valeura.

‘Reserves replacement ratio’ for 2025 is calculated by dividing the difference in reserves between the NSAI 2025 Report and the NSAI 2024 Report, plus actual 2025 production, by the assets’ total production before royalties for the calendar year 2025.

‘RLI’ is calculated by dividing reserves by management’s estimated total production before royalties for 2026.

‘End of field life’ is calculated by NSAI as the date at which the monthly net revenue generated by the field is equal to or less than the asset’s operating cost.

Reserves

Reserves are estimated remaining quantities of commercially recoverable oil, natural gas, and related substances anticipated to be recoverable from known accumulations, as of a given date, based on the analysis of drilling, geological, geophysical, and engineering data, the use of established technology, and specified economic conditions, which are generally accepted as being reasonable. Reserves are further categorised according to the level of certainty associated with the estimates and may be sub-classified based on development and production status.

Proved reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves.

Developed reserves are those reserves that are expected to be recovered from existing wells and installed facilities or, if facilities have not been installed, that would involve a low expenditure (e.g., when compared to the cost of drilling a well) to put the reserves on production.

Developed producing reserves are those reserves that are expected to be recovered from completion intervals open at the time of the estimate. These reserves may be currently producing or, if shut in, they must have previously been on production, and the date of resumption of production must be known with reasonable certainty.

Developed non-producing reserves are those reserves that either have not been on production, or have previously been on production, but are shut in, and the date of resumption of production is unknown.

Undeveloped reserves are those reserves expected to be recovered from known accumulations where a significant expenditure (e.g., when compared to the cost of drilling a well) is required to render them capable of production. They must fully meet the requirements of the reserves classification (proved, probable, possible) to which they are assigned.

Probable reserves are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves.

Possible reserves are those additional reserves that are less certain to be recovered than probable reserves. It is unlikely that the actual remaining quantities recovered will exceed the sum of the estimated proved plus probable plus possible reserves. There is a 10% probability that the quantities actually recovered will equal or exceed the sum of the estimated proved plus probable plus possible reserves.

The estimated future net revenues disclosed in this news release do not necessarily represent the fair market value of the reserves associated therewith.

The estimates of reserves and future net revenue for individual properties may not reflect the same confidence level as estimates of reserves and future net revenue for all properties, due to the effects of aggregation.

Contingent Resources

Contingent resources are those quantities of petroleum estimated, as of a given date, to be potentially recoverable from known accumulations using established technology or technology under development, but which are not currently considered to be commercially recoverable due to one or more contingencies. Contingencies are conditions that must be satisfied for a portion of contingent resources to be classified as reserves that are: (a) specific to the project being evaluated; and (b) expected to be resolved within a reasonable timeframe.

Contingent resources are further categorised according to the level of certainty associated with the estimates and may be sub‐classified based on a project maturity and/or characterised by their economic status. There are three classifications of contingent resources: low estimate, best estimate and high estimate. Best estimate is a classification of estimated resources described in the Canadian Oil and Gas Evaluation Handbook as the best estimate of the quantity that will be actually recovered; it is equally likely that the actual remaining quantities recovered will be greater or less than the best estimate. If probabilistic methods are used, there should be at least a 50 percent probability that the quantities actually recovered will equal or exceed the best estimate.

The project maturity subclasses include development pending, development on hold, development unclarified and development not viable. The contingent resources disclosed in this news release are classified as either development unclarified, development not viable, or development on hold.

Development unclarified is defined as a contingent resource that requires further appraisal to clarify the potential for development and has been assigned a lower chance of development until commercial considerations can be clearly defined. Chance of development is the likelihood that an accumulation will be commercially developed.

Conversion of the development unclarified resources referred to in this news release is dependent upon (1) the expected timetable for development; (2) the economics of the project; (3) the marketability of the oil and gas production; (4) the availability of infrastructure and technology; (5) the political, regulatory, and environmental conditions; (6) the project maturity and definition; (7) the availability of capital; and, ultimately, (8) the decision of joint venture partners to undertake development.

The major positive factor relevant to the estimate of the contingent development unclarified resources referred to in this news release is the successful discovery of resources encountered in appraisal and development wells within the existing fields. The major negative factors relevant to the estimate of the contingent development unclarified resources referred to in this news release are: (1) the outstanding requirement for a definitive development plan; (2) current economic conditions do not support the resource development; (3) limited field economic life to develop the resources; and (4) the outstanding requirement for a final investment decision and commitment of all joint venture partners.

Development not viable is defined as a contingent resource where no further data acquisition or evaluation is currently planned and hence there is a low chance of development, there is usually less than a reasonable chance of economics of development being positive in the foreseeable future. The major negative factors relevant to the estimate of development not viable referred to in this news release are: (1) current economic conditions do not support the resource development; and (2) availability of technical knowledge and technology within the industry to economically support resource development.

Development on hold is defined as a contingent resource where there is a reasonable chance of development, but there are contingencies to be resolved before the project can move forward.

If these contingencies are successfully addressed, some portion of these contingent resources may be reclassified as reserves.

Of the best estimate 2C contingent resources estimated in the NSAI 2025 Report, on a risked basis: 63% of the estimated volumes are light/medium crude oil, with the remainder being heavy oil; 42% are categorised as Development Unclarified, with the remainder being Development Not Viable. Development Unclarified 2C resources have been assigned an average chances of development for the four fields ranging from 5% to 85%, while 2C Development Not Viable resources have been assigned an average chance of development ranging from 10% to 15%.

Contingent resources within the Development on hold category are only in the 1C certainty estimate (low or conservative). The main contingencies are licence extensions and continuation of drilling beyond five years. These contingencies are considered to have a high chance of positive resolution and are therefore not applied in the best estimates of respective reserves and resources (2P and 2C).

The NSAI estimates have been risked, using the chance of development, to account for the possibility that the contingencies are not successfully addressed.

Glossary

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, management’s anticipation that completion of the Farm-in Transaction will be additive to volumes and values; management’s expectation of receiving governmental approval of the Farm-in Transaction and the timing thereof; management’s continued focus on contingent resources and the anticipated growth of resources; the ability to add more years of future cash flow, for the benefit of all stakeholders; the ability to drive deeper and longer-lived value from the Company’s assets, even when faced with a correction in commodity prices; the Company’s anticipated 2026 production guidance of 19.5 – 22.5 Mbbls/d; dates for the anticipated end of field life of Valeura’s assets; forecast oil prices; the Company’s intention to disclose a summary of the NSAI 2025 Report to Thailand’s upstream regulator and the anticipated timing thereof; and the anticipated filing date of the Company’s annual information form along with its estimates of reserves and resources.

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; 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; royalty rates and taxes; 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 ability to efficiently integrate assets and employees acquired through acquisitions; global energy policies going forward; 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; 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, 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.

The forward-looking information contained in this new 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 new 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.

SOURCE: Valeura Energy Inc.

View the original press release on ACCESS Newswire

Relationship Represents Potential Long Term Scalability of High Efficiency Supply Chain from Demonstration to Commercial Scale

Syntholene Energy CORP (TSXV: ESAF) (FSE: 3DD0) (OTCQB: SYNTF) (‘Syntholene’ or the ‘Company’) announces that it has selected Dynelectro ApS (Denmark) as the electrolyzer technology vendor for its planned synthetic fuel demonstration facility in Iceland. Dynelectro is the developer of what it describes as the world’s most efficient electrolyzer platform, purpose-built for high-performance hydrogen production in power-to-liquids applications for synthetic fuel (‘eFuel’) and, more specifically, synthetic sustainable aviation fuel (‘eSAF’).

Dynelectro’s electrolyzer platform has demonstrated industry-leading energy efficiency in the production of hydrogen, a key feedstock to eFuels, while maintaining durability under continuous industrial operation at variable load. The system architecture emphasizes reduced balance-of-plant complexity, high current density operation, and modular deployment, characteristics that align closely with Syntholene’s objective of developing capital-efficient, repeatable synthetic fuel infrastructure.

The planned demonstration facility is intended to validate the Company’s integrated approach to producing low-cost hydrogen as a feedstock to eSAF and other eFuels, with a focus on scalability, energy efficiency, and long-term cost competitiveness with fossil fuels.

‘Syntholene’s eSAF production plans are a perfect match for Dynelectro’s electrolyser solution,’ explains Sune Lilbaek, CEO at Dynelectro ApS. ‘To be successful in the eSAF market, the lowest possible cost of hydrogen over the lifespan of the plant is a necessity. Dynelectro’s unique take on SOEC electrolysers seeks to enable the lowest possible energy consumption and maintenance cost. When integrated with Syntholene’s proprietary hybrid thermal production system, it is possible to convert up to 90% of the renewable electrical energy supplied into clean hydrogen. Together, we expect to be deploying the most cost-effective, energy-efficient solution for production of sustainable aviation fuel on the market today.’

The vendor selection represents a key technical milestone for Syntholene as it advances engineering and procurement activities associated with its first demonstration-scale facility.

‘The selection of Dynelectro is the result of a rigorous two-year technical and commercial evaluation process across all major vendors focused on efficiency, reliability, and long-term scalability,’ said Dan Sutton, CEO of Syntholene. ‘Electrolyzer performance coupled with low-cost clean energy are the primary drivers of synthetic fuel economics. Partnering with a technology provider that prioritizes energy efficiency and industrial robustness is critical as we move from demonstration toward multi-megawatt commercial deployment.’

About Syntholene

Syntholene is actively commercializing its novel Hybrid Thermal Production System for low-cost clean fuel synthesis. The target output is ultrapure synthetic jet fuel, manufactured at 70% lower cost than the nearest competing technology today. The company’s mission is to deliver the world’s first truly high-performance, low-cost, and carbon-neutral synthetic fuel at an industrial scale, unlocking the potential to produce clean synthetic fuel at lower cost than fossil fuels, for the first time.

Syntholene’s power-to-liquid strategy harnesses thermal energy to power proprietary integrations of hydrogen production and fuel synthesis. Syntholene has secured 20MW of dedicated energy to support the Company’s upcoming demonstration facility and commercial scale-up.

Founded by experienced operators across advanced energy infrastructure, nuclear technology, low-emissions steel refining, process engineering, and capital markets, Syntholene aims to be the first team to deliver a scalable modular production platform for cost-competitive synthetic fuel, thus accelerating the commercialization of carbon-neutral eFuels across global markets.

About Dynelectro

Dynelectro is a Danish SOE electrolyser OEM at the forefront of developing advanced, sustainable energy solutions. Utilising cutting-edge solid-oxide electrolysis technology, Dynelectro achieves unprecedented system performance and lifespan, enabling a five-fold improvement in lifetime performance through a novel approach to stack control and integration. Their innovations enable operators to seamlessly adjust production based on the availability of cost-effective renewable energy.

The company commercialises MW-scale Dynamic Electrolyser Units (DEUs), producing clean hydrogen to unlock syngas and e-fuel production. Dynelectro was founded in 2018 and is headquartered in the capital region of Denmark. Visit www.dynelectro.dk

Forward-Looking Statements
This press release contains forward-looking statements within the meaning of applicable securities laws. The use of any of the words ‘expect’, ‘anticipate’, ‘aims’, ‘continue’, ‘estimate’, ‘objective’, ‘may’, ‘will’, ‘project’, ‘should’, ‘believe’, ‘plans’, ‘intends’ and similar expressions are intended to identify forward-looking information or statements. All statements, other than statements of historical fact, including but not limited to statements regarding the use of a particular vendor, the services to be provided and standard of delivery, expected benefits of engagement of certain service providers, development of the Company’s test facility, commercial scalability, technical and economic viability, anticipated geothermal power availability, anticipated benefit of eFuel, the Company’s business plans, and future commercial opportunities, are forward-looking statements.

The forward-looking statements and information are based on certain key expectations and assumptions made by the Company, including without limitation the assumption that the Company will be able to execute its business plan, that the eFuel will have its expected benefits, that the selected vendor will be able to complete their deliverables on time and to the standard expected, that the test facility will be completed as planned, that there will be market adoption, and that the Company will be able to access financing as needed to fund its business plan. Although the Company believes that the expectations and assumptions on which such forward-looking statements and information are based are reasonable, undue reliance should not be placed on the forward-looking statements and information because the Company can give no assurance that they will prove to be correct. Since forward-looking statements and information address future events and conditions, by their very nature, they involve inherent risks and uncertainties.

Actual results could differ materially from those currently anticipated due to a number of factors and risks, including, without limitation, Syntholene’s ability to meet production targets, realize projected economic benefits, meet targeted timelines for development, overcome technical challenges, secure financing, maintain regulatory compliance, manage geopolitical risks, and successfully negotiate definitive terms. Syntholene does not undertake any obligation to update or revise these forward-looking statements, except as required by applicable securities laws.

Readers are advised to exercise caution and not to place undue reliance on these forward-looking statements.

To view the source version of this press release, please visit https://www.newsfilecorp.com/release/283350

(TheNewswire)

Vancouver, B.C. TheNewswire – February 9, 2026 Armory Mining Corp. (CSE: ARMY) (OTC: RMRYF) (FRA: 2JS) (the ‘Company’ or ‘Armory’) a resource exploration company focused on the discovery and development of minerals critical to the energy, security and defense sectors, is pleased to announce that is preparing to conduct a series of airborne geophysics surveys at the Ammo antimony-gold project (‘Ammo’) located in Nova Scotia, Canada.

The planned airborne geophysics surveys have been designed using efficient 50-meter flight lines (Fig 1) to collect information from associated sulfide mineralization, sericite and potassic alteration and probable pathfinder related uranium anomalies.

The Company intends on undertaking a magnetic survey designed to collect information regarding geological characteristics including structural and lithological features, an electromagnetic survey to collect data correlated with associated sulfide mineralization, and a radiometric survey to collect any possible correlation between uranium anomalies and the target mineralization.

‘These surveys form an important part of preliminary exploration critical to defining drill targets at Ammo,’ said Alex Klenman, CEO of Armory Mining. ‘The data generated by the surveys will aid tremendously in determining the best areas to drill.  The geological team has outlined a comprehensive exploration plan for the Ammo project, and we’re committed to completing these next steps,’ continued Mr. Klenman.  

Click Image To View Full Size

Figure 1 – Ammo Property and Significant Mining and Mineral Occurrences within and adjacent Distance

The Property

• The Company has the option to acquire a 100% interest in the Ammo Sb-Au project, comprising three contiguous mineral claims (Exploration Licenses) surrounding the historical West Gore antimony-gold mine, a past producer of antimony and gold, located in central Nova Scotia, Canada covering approximately 3,020 hectares (Fig. 2). 

• The property is underlain by sericitic slates and minor intercalated arenites of the Halifax formation, a member of the Ordovician Meguma Group. It is made up of a basal sandy flysch unit known as the Goldenville formation and an overlying shaly flysch unit known as the Halifax formation which hosts the West Gore gold-antimony mineralization. Peraluminous granites and minor mafic bodies intrude the Meguma Group sedimentary. This magmatic activity seems to be responsible for the hydrothermal activity that caused the gold mineralization (Fig 2). 

• The mineralization in adjacent West Gore mineralization occurs throughout the Meguma Group stratigraphy. The mineralization is generally in laterally continuous veins were emplaced during hydrofracturing in brittle ductile deformation dominated by quartz-carbonate gangue and iron sulphides with free gold, generally micron sized but nuggets up to 11 ounces have been reported. The sulfides with mineralization including Pyrite, pyrrhotite, arsenopyrite, stibnite, chalcopyrite, galena, sphalerite and iron oxides are associated with quartz-carbonate veins or sheared host rocks in the Mineralized zone. 

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Figure 2 – Ammo Property and Surrounding Mining and Mineral Occurrences

About Armory Mining Corp

Armory Mining Corp. is a Canadian exploration company focused on minerals critical to the energy, security and defense sectors. The Company controls an 80% interest in the Candela II lithium brine project located in the Incahuasi Salar, Salta Province, Argentina. In addition, the Company controls 100% interest in both the Ammo antimony-gold project located in Nova Scotia and the Riley Creek antimony-gold project located in British Columbia.

Qualified Person

The technical content of this news release has been reviewed and approved by Mr. Babak V. Azar, P.Geo., a qualified person as defined by National Instrument 43-101. Historical reports provided by the optionor were reviewed by the qualified person. The information provided has not been verified and is being treated as historic.

Contact Information

Alex Klenman

CEO & Director

alex@armorymining.com

604-970-4330

Neither the Canadian Securities Exchange nor its Market Regulator (as the term is defined in the policies of the Canadian Securities Exchange) accepts responsibility for the adequacy of accuracy of this news release.   This news release does not constitute an offer to sell or a solicitation of an offer to buy nor shall there be any sale of any of the Company’s securities in any jurisdiction in which such offer, solicitation or sale would be unlawful, including any of the securities in the United States of America. The Company’s securities have not been and will not be registered under the United States Securities Act of 1933, as amended (the ‘1933 Act’) or any state securities laws and may not be offered or sold within the United States or to, or for account or benefit of, U.S. Persons (as defined in Regulation S under the  1933 Act) unless registered under the  1933 Act  and applicable  state  securities  laws, or an exemption from such registration requirements is available.

Forward-looking statements:

This press release contains certain forward-looking statements, including statements regarding the intended use of funds. The words ‘expects,’ ‘anticipates,’ ‘believes,’ ‘intends,’ ‘plans,’ ‘will,’ ‘may,’ and similar expressions are intended to identify forward-looking statements. Although the Company believes that its expectations as reflected in these forward-looking statements are reasonable, such statements involve risks and uncertainties. Actual results may differ materially from those expressed or implied in these statements due to various factors, including, but not limited to, political and regulatory risks in Canada, operational and exploration risks, market conditions, and the availability of financing. Readers are cautioned not to place undue reliance on forward-looking statements, which are made as of the date of this release. The Company undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise, except as required by applicable securities laws.

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First drill testing of a large-scale Rossing-style uranium target, along trend of Namibia’s giant uranium deposits

ReeXploration Inc. (TSXV: REE) (FSE: K2I0) (‘ReeXploration’ or the ‘Company’) is pleased to announce the launch of a fully funded uranium drilling program at the Eureka Project in central Namibia. This campaign marks the Company’s first drill testing of a large-scale uranium target, 6.5 x 3.5 km in extent, defined through integrated geophysical, geochemical, and geological work. The target is located along trend of Namibia’s world renowned ‘Alaskite Alley’, a corridor hosting giant leucogranite-hosted uranium deposits.

The drill campaign will evaluate a range of priority zones distributed across the broader target area, selected on the basis of airborne and ground uranium radiometric responses, uranium-in-soil geochemistry, and interpreted favourable structural and lithological settings. The priority zones all fall within a regional geological setting consistent with leucogranite-hosted uranium systems elsewhere in Namibia’s Central Zone, including the Rössing, Husab, and Etango deposits.

The core drilling program is expected to include up to 2,000 metres of drilling across 12 to 15 drill holes, and will be results-driven. Drill holes are designed to test for primary leucogranite-hosted uranium mineralization below the weathering profile.

‘The start of drilling at Eureka marks a significant milestone for ReeXploration, representing our first drill program on a large and highly prospective uranium system,’ said Christopher Drysdale, Interim CEO of ReeXploration. ‘This initial campaign will evaluate several priority zones and generate critical information to refine our geological understanding and guide future exploration. Importantly, Eureka also hosts confirmed rare earth element mineralization, providing the Company with dual-commodity exposure and long-term strategic optionality. Operating in Namibia, with its proven history of supporting responsible exploration and development, significantly enhances our ability to advance and unlock the full potential of the Eureka Project.’

Figure 1: Regional satellite view showing the position of the uranium anomalies southwest of the Eureka Dome, and their proximity to the Welwitschia Lineament and other large uranium deposits in Alaskite Alley.

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Program Overview and Next Steps

The initial drilling phase (up to 2,000 metres in 12 to 15 drill holes) is designed to provide first-pass testing of the uranium system at depth and to validate the geological model developed from recent radiometric surveys, soil geochemistry, and field mapping.

Priority zones for drill testing have been identified based on coincident:

• Airborne uranium radiometric anomalies
• High total gamma responses (>500 cps) from ground spectrometer surveys
• Uranium-in-soil anomalies (>10 ppm U) identified by pXRF analysis
• Interpreted leucogranites in contact with reactive calc-silicate host rocks

The zones include occurrences of visible secondary uranium mineralization identified within leucogranites and gypcretes/calcretes.

Drilling will consist of core drill holes designed to confirm the presence, style, and continuity of uranium mineralization at depth, and to improve the Company’s understanding of the broader uranium system across the Eureka Project area.

Figure 2: Company license holding showing REE targets within the Eureka Dome, and airborne uranium anomalies (Government Airborne Radiometrics) backdrop. Insert: Thorium radiometric backdrop showing low thorium relative to the uranium anomalies.

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Qualified Person

Tolene Kruger, BSc. (Hons), M.Sc., is a consulting geologist and has reviewed and approved the scientific and technical information in this news release. Ms. Kruger is registered as Professional Natural Scientist (Pr.Sci.Nat.) with the South African Council for Natural Science Professions (SACNASP, Reg. No.: 148182), and a Qualified Person for the purposes of National Instrument 43-101 – Standards of Disclosure for Mineral Projects. Ms. Kruger is not independent of the Company under NI 43-101.

About ReeXploration Inc.

ReeXploration (TSXV: REE) (FSE: K2I0) is a Canadian exploration company positioned to help meet surging global demand for secure, responsible supplies of critical minerals essential to the clean energy transition, advanced technologies and national defense. The Company’s flagship Eureka Project in central Namibia pairs a technically proven rare earth foundation – supported by the production of a clean monazite concentrate – with a newly defined, high-priority uranium target located within one of the world’s most established uranium corridors. Together, these commodities provide multi-path discovery potential aligned with accelerating global efforts to diversify critical mineral and nuclear fuel supply. Supported by a Namibia-based technical team and guided by global critical minerals experts, ReeXploration is advancing a disciplined, discovery-led strategy, building a credible, ESG-aligned platform positioned to benefit from the global race to diversify and secure responsible supply chains.

Caution Regarding Forward Looking Information

This press release may contain forward-looking information. This information is based on current expectations and assumptions (including assumptions relating to general economic and market conditions) that are subject to significant risks and uncertainties that are difficult to predict. Actual results may differ materially from results suggested in any forward-looking information. ReeXploration does not assume any obligation to update forward-looking information in this release, or to update the reasons why actual results could differ from those reflected in the forward-looking information unless and until required by securities laws applicable to ReeXploration. Additional information identifying risks and uncertainties is contained in the filings made by ReeXploration with Canadian securities regulators, which filings are available at www.sedarplus.ca.

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

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