Fervo Energy raised 1.89 billion dollars in a single share sale in May, the largest climate tech listing of the year. Eavor’s flagship European project needed a stack of grants, a European Investment Bank loan, and financing from three separate international banks to reach a fraction of that sum. The gap between those two financing models, more than any resource shortfall, is what a delayed EU strategy has failed to close.
The European Commission’s Electrification Action Plan, published on July 17, arrived without the companion Geothermal Action Plan that EU energy ministers had requested in their Council conclusions of December 2024 and that the European Parliament had separately called for. That is not the first delay. The plan was expected to accompany the Commission’s Affordable Energy Action Plan in March 2025 and did not appear then either. By December 2025, the European Geothermal Energy Council was still pressing the Commission to publish a dedicated strategy in the first quarter of 2026, a deadline that has since passed. The Commission’s actual response, buried in the July package, is a commitment to establish a Geothermal Stakeholder Partnership by the first quarter of 2027, a body meant to identify regulatory, technical, and investment barriers rather than a funded deployment plan. The European Geothermal Energy Council and more than sixty co-signing businesses, investors, and think tanks have warned that this response risks concentrating on geothermal heat, where deployment is already comparatively established, at the expense of next-generation power generation, where Europe’s competitive position is weakest.
The technology gap that is widening is easiest to see in how each region finances its flagship projects. Eavor’s Geretsried facility in Bavaria, the first commercial-scale deployment of its closed-loop technology and the model project cited for European progress, was built on a EUR 91.6 million grant from the EU Innovation Fund plus a EUR 45 million loan from the European Investment Bank, itself backed by the InvestEU guarantee program, alongside co-financing from Japan’s development bank and two commercial lenders, for a project with a total cost of roughly EUR 350 million. Assembling that package required stitching together a grant, a guaranteed loan, and export-credit-backed international bank financing for a single demonstration plant. Fervo Energy, whose flagship Cape Station project in Utah is already delivering power under a contracted 115-megawatt agreement with Google and NV Energy and is fully contracted to reach 500 megawatts by 2028, raised more than that entire Bavarian financing stack, 1.89 billion dollars, in one Nasdaq listing in May, pricing at a valuation of 7.7 billion dollars before its shares rose a further 33% on debut. The difference is not primarily about the underlying geology or drilling technology, since Eavor and Fervo both draw on oil and gas drilling techniques and both count hyperscale data center demand as a core commercial driver. It is that one project could tap public equity markets already primed to underwrite firm, round-the-clock clean power for AI data centers, while the other depended on the EU’s project-by-project grant architecture.
The American approach that produced that market confidence had a specific design. The Department of Energy’s Enhanced Geothermal Shot, launched in 2022, set a target of cutting the levelized cost of enhanced geothermal systems by 90% to 45 dollars per megawatt-hour by 2035, not by 2050. Separately, the DOE’s 2024 commercial liftoff analysis projects that next-generation geothermal could supply 90 gigawatts of US capacity by 2050, rising to as much as 300 gigawatts depending on storage technology and market conditions, a figure notably higher than the 60 gigawatts sometimes cited for the program. The Frontier Observatory for Research in Geothermal Energy, the field laboratory the DOE funded to de-risk drilling and stimulation techniques before handing the technology to industry, produced the results Fervo built on. That sequencing, publicly funded field validation followed by a deliberate handoff to private capital, is precisely what EGEC and the Clean Air Task Force have asked Brussels to replicate through a European exploration risk-sharing facility, and precisely what the postponed Action Plan was supposed to establish.
Canada’s version of the same model is smaller but similarly structured. Alberta’s Emissions Reduction Alberta agency, funded through the province’s industrial carbon levy, awarded Eavor 8 million dollars in July toward an 83 million dollar project advancing its next-generation Eavor-Jules technology, aimed at reaching higher-temperature resources. That public contribution is modest next to Eavor’s roughly 365 million dollars in total funding raised to date, but it follows the same de-risking logic as the FORGE program: government money absorbs the technical risk on the hardest engineering step, and private and corporate capital, including equity from BP Ventures, Temasek, and Microsoft’s Climate Innovation Fund, follows once the risk narrows. Eavor’s recognition as the second-ranked company on TIME’s 2026 World’s Top GreenTech Companies list, behind fellow Canadian firm General Fusion, reflects that momentum, though it is worth noting the ranking is a composite of environmental impact, innovation and financial strength scored by Statista rather than a measure of deployed capacity, and only one Eavor plant is currently delivering commercial power anywhere, the Bavarian facility that began supplying the German grid in December.
Europe’s underlying resource estimates also vary widely enough to underline how thin the continent’s own data infrastructure remains, one of the specific gaps EGEC’s proposal asks Brussels to fund. The commonly cited figure that next-generation geothermal could economically supply roughly 300 terawatt-hours of EU electricity annually, about a tenth of current demand, at costs below EUR 100 per megawatt-hour, sits far below the Clean Air Task Force’s separate estimate that capturing just 1% of Europe’s high-temperature geothermal resource could generate close to 18,000 terawatt-hours a year. Those numbers are not measuring the same thing: one describes a realistically deployable near-term technical and economic case, and the other a theoretical raw resource, but the three-order-of-magnitude spread is itself evidence for the point that better shared geological data, one of the concrete asks in EGEC’s proposal, is still missing at the EU level.
None of this reflects a shortage of European capability. Germany’s Geothermal Energy Acceleration Act and Eavor’s own choice to make Bavaria its first commercial deployment, ahead of any project in its home market of Canada, point to a continent with drilling expertise transferable from its oil and gas sector, engineering capacity, and, in district heating networks, existing infrastructure that the US, in particular, largely lacks. Spain offers a live demonstration of what domestically generated clean power can already do for energy security, even without geothermal in the mix: Ember’s analysis found that wind and solar growth cut the share of hours in which gas set Spanish electricity prices from 52% in 2021 to 9% in the first months of 2026, saving a typical household on the regulated tariff about EUR10 a month, roughly 19%, during the gas price spike that followed the escalation of the Iran conflict this year. That is the kind of insulation from imported fossil fuel volatility that a geothermal buildout is meant to extend into firm, dispatchable power rather than weather-dependent generation. The absence of a funded EU framework to do that is now a matter of sequencing rather than geology, and every quarter the Geothermal Stakeholder Partnership slips further from its promised 2027 start date is a quarter in which American and Canadian developers convert public seed funding into the kind of capital-market validation that a single IPO can now demonstrate and a single European demonstration project still cannot.
