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CanCambria Energy Corp
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CanCambria Energy Reports Higher Estimated NPV10 for Southern Hungary Gas Project
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Announcement Summary
CanCambria Energy Corp. (TSXV: CCEC) (FSE: 4JH) (OTCQB: CCEYF) announced an updated independent contingent resource evaluation for its deep gas project in southern Hungary.
- The report covers the Company’s 100% WI, BA-IX Mining Plot and Kiskunhalas Concession Area, and was prepared by Chapman Hydrogen and Petroleum Engineering Ltd (CHPE).
- CHPE used a US$12.00/MMBtu (TTF1) long-term gas-price assumption and a mid-2027 first-gas date in the development model.
- The 2C Development Pending risked NPV10 was estimated at US$2.04 billion, from $1.762 billion previously; the source also states a 16% increase.
- The 2C Development Pending best estimate remains 571.9 Bcf of natural gas and 59.6 MMbbl of condensate, net risked recoverable.
- Combined best estimate 2C contingent resources for all classes are 1.1 trillion cubic feet of natural gas and 116.6 million barrels of condensate.
- The model includes full-field development increasing in 2028 to six wells per year and an inventory of 112 wells.
CHPE assigned the contingent-resource volumes an 80% chance of development. They remain contingent until additional delineation wells, commercial-plan refinement, regulatory approval for full-field development, corporate commitment, and financing. Commercial viability remains uncertain. The updated evaluation can be downloaded from SEDAR+.
Investor FAQs
On August 10, 2026, CanCambria Energy Corp. announced an updated independent contingent resource evaluation for its deep gas project in southern Hungary. The company is identified in the source as CanCambria Energy Corp. (TSXV: CCEC), (FSE: 4JH) and (OTCQB: CCEYF). The Resources Report was prepared by Chapman Hydrogen and Petroleum Engineering Ltd (CHPE), an independent qualified reserves evaluator, dated July 1, 2026 and effective as of June 30th, 2026.
The source states that the estimated NPV10 for the base-case, risked 2C Development Pending contingent resource increased by 16%, from $1.762 billion to $2.04 billion, based on updated pricing assumptions. It also states that the 2C Development Pending best estimate contingent resource is 571.9 Bcf and 59.6 MMbbl, net risked recoverable, and is unchanged. The combined best estimate 2C contingent resources for all classes are stated as 1.1 trillion cubic feet of natural gas and 116.6 million barrels of condensate net to the company.
CHPE adopted a US$12.00/MMBtu (TTF¹) long-term European natural gas price assumption, compared with the previous US$10.00/MMBtu (TTF1) base-case assumption. The evaluation also uses a Brent crude oil price assumption of US$65.00 per barrel. The source states that European natural gas day-ahead spot prices are currently US$18.50/MMBtu (TTF¹), while the six-month trailing average and trailing 5-year average each exceed US$15.00/MMBtu. The NPV10 estimates are based on estimates of future operating and capital costs and CHPE’s forecast prices as of July 1, 2026, and do not represent the fair market value of the resources.
The field development model in the source has first production commencing in mid-2027 and full field development increasing in 2028 to six wells per year, with an inventory of 112 wells. These are model assumptions and forward-looking information. The source states that there can be no certainty that the project will be developed on the timelines outlined within the Resources Report.
CHPE assigned the contingent resource volumes an 80% chance of development. The source states that there is uncertainty over whether it will be commercially viable to produce any portion of the reported contingent resource volumes, and that there is no guarantee the estimated resources will be recovered. Contingent resources remain subject to additional delineation wells confirming reservoir quality and continuity, refinement of the commercial development plan, regulatory approval for full field development, corporate commitment to move forward and financing for commercial development. Contingencies may also include economic, legal, environmental, political and regulatory matters or a lack of markets.
The source attributes the revised valuation to a stronger long-term outlook for European natural gas prices amid heightened macro-geopolitical uncertainty, tightening supply-side fundamentals and increasing concerns over European energy security. It also refers to recent tensions involving Iran and broader instability across the Middle East. These points are presented as factors in the company’s and CHPE’s assessment, rather than as guarantees of future prices or project outcomes.
The company states that forward-looking information, including the estimated NPV10, the 2C Development Pending estimate, potential first gas production commencing in 2027 and the advancement of the Kiskunhalas Project, may not be realised as contemplated, or at all. It identifies risks relating to the Resources Report estimates, project advancement, exploration plans, business plans, expectations, capital costs and objectives. The company also states that forward-looking information is subject to known and unknown risks, uncertainties, assumptions and other unpredictable factors, many of which are beyond its control.
The source states that the updated resources evaluation can be downloaded from SEDAR+. It also states that full disclosure with respect to the company’s resources will be contained in its Form 51-101F1 for the year ended December 31, 2026, which will be filed on SEDAR+ (www.sedarplus.com).
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