Key Takeaways

• Nine projects selected across Greece, Spain, Denmark, Austria, Finland, Germany and Norway — total EU funding €1.09 billion from ETS revenues.
• Bid prices range from €0.44/kg (Finland’s 500 MW Cloudberry project) to €3.49/kg (Norwegian maritime hydrogen), against a ceiling of €4.00/kg — far below the €4.50/kg ceiling of the first auction.
• The auction widens scope from RFNBO-only to include electrolytic low-carbon hydrogen for the first time, operationalising the new EU Hydrogen and Gas Market framework.
• Germany and Spain committed €1.3 billion and €440 million respectively via the Auction-as-a-Service mechanism — more than doubling the headline EU budget for qualifying projects.
• 58 bids were received requesting €8.4 billion: a 10:1 oversubscription ratio that gives the Commission price discovery data across a wide range of project economics.
• Project attrition in the second auction (IF24) — where only 6 of 15 originally selected projects reached grant signature — means the real test of IF25 is delivery, not selection.

Background: What Is the European Hydrogen Bank?

The European Hydrogen Bank (EHB) was established by the European Commission in 2023 as the principal mechanism for bridging the cost gap between renewable and low-carbon hydrogen and fossil fuel incumbents. Its central tool is a competitive auction that awards a fixed production premium per kilogram of certified hydrogen, funded from revenues generated by the EU Emissions Trading System (EU ETS).

The design is deliberately minimalist. There is no capex grant, no construction guarantee and no guaranteed offtake. Instead, the Bank says: if you build a compliant plant, produce certified molecules, and survive the first years of operation, we will top up your revenue per kilogram at whatever level you bid — for up to a decade. That keeps the subsidy tied to real-world delivery rather than project intention.

The Auction History: Three Rounds in Three Years

The first EU hydrogen auction (pilot, 2023–2024) attracted 132 bids and awarded €720 million to seven projects with bid prices between €0.37/kg and €0.48/kg, against a €4.50/kg ceiling. The clearing level shocked many observers who had expected the ceiling to be much more binding. The second auction (IF24, 2024–2025) attracted 61 bids, with average subsidy requests below €0.70/kg — roughly half the pilot average — suggesting rapid cost learning and more sophisticated project economics. However, only 6 of 15 originally selected projects in IF24 proceeded to grant signature, a consequence of bankability constraints, the 8–10% completion guarantee requirement, and the difficulty of securing long-term offtake.

The IF25 round, the third European Hydrogen Bank auction, draws on these lessons. Maturity requirements have been tightened, the scope has been widened, and the Auction-as-a-Service mechanism has attracted significantly larger national commitments from Germany and Spain.

Auction Design: Three Topics, One Mechanism

The IF25 EU hydrogen auction was structured around three topic baskets with separate budgets, a single bid cap of €4.00/kg, and a pay-as-bid ranking mechanism. Projects compete within their chosen topic on price alone; no quality scoring, no narrative weighting.

Key Eligibility Requirements

• Minimum electrolyser capacity: 5 MWe at a single site.
• RFNBO compliance: must satisfy additionality, temporal correlation and geographic correlation rules under the Renewable Energy Directive (RED III).
• Low-carbon electrolytic hydrogen (Topic 2 and 3): must demonstrate a minimum 70% GHG emissions reduction relative to the fossil fuel baseline across the full system boundary.
• Entry into operation: within five years of grant agreement signature.
• Financial close: within two and a half years of grant agreement signature.
• Support period: fixed premium payments for a maximum of ten years, paid semi-annually in arrears after verified and certified production.

The Auction-as-a-Service (AaaS) Mechanism

A structural feature of IF25 is the formal Auction-as-a-Service mechanism, through which CINEA (the European Climate, Infrastructure and Environment Executive Agency) runs the evaluation and ranking on behalf of participating Member States, who then deploy national funds to qualifying projects outside the EU Innovation Fund budget. Germany committed €1.3 billion of national funding to RFNBO projects. Spain committed €440 million via its Recovery and Resilience Facility. This means that for eligible projects, the effective support available via the combined EU-plus-national stack exceeded €3 billion — more than double the Innovation Fund headline figure.

The design rationale is explicit in the Commission’s state aid decisions: AaaS “harmonises and ties together national and European support schemes, increasing the comparability of price points from subsidy schemes, and saving on the administrative costs of Member States and project developers.” In other words, it is an attempt to build a single, integrated European hydrogen auction market rather than a patchwork of national programmes with different rules, different bid formats and different subsidy levels. For an analysis of how fragmented national approaches have stalled UK hydrogen, see the note on UK Hydrogen Infrastructure.

IF25 Auction Results — Published 7 May 2026

Nine projects across seven countries were invited to the Grant Agreement Preparation (GAP) process. Total EU Innovation Fund commitment: €1.09 billion. Collective electrolyser capacity: almost 1.1 GW. Projected hydrogen production over ten years: over 1.3 million tonnes.

Topic 1: RFNBO General (€600 million available)

Topic 2: RFNBO + Low-Carbon Electrolytic Hydrogen (€400 million available)

Topic 3: Maritime and Aviation (€300 million available)

Main Analysis: What the Numbers Actually Tell You

The IF25 results are striking in three respects: the lowest bid, the bifurcation in the topic structure, and the stark premium gap between general and maritime projects. Taken together, they reveal a market that is maturing quickly in some segments but remains structurally challenged in others.

The Cloudberry Signal: €0.44/kg Changes the Benchmark

The lowest bid in the entire auction — and indeed the lowest bid in any European Hydrogen Bank auction to date — was €0.44/kg from Finland’s Cloudberry project, coordinated by Vetyalfa Oy, a subsidiary of the renewables developer Tuulialfa. At 500 MWe, it is also the largest single project selected, with projected output of over 508,000 tonnes over ten years.

Cloudberry sits in Topic 2, meaning it qualifies as low-carbon electrolytic hydrogen — not strictly RFNBO — which means it benefits from Finland’s very low-carbon grid profile (nuclear-heavy, with significant hydro and wind). The 70% GHG reduction threshold is accessible in that context without the full cost burden of hourly temporal correlation, geographic correlation requirements and dedicated renewable PPA that RFNBO compliance demands. This is an important price signal: where grid decarbonisation is advanced, electrolytic hydrogen can be produced at a cost premium over fossil hydrogen that is genuinely low, and the remaining gap can be closed with modest auction support.

In practical terms, €0.44/kg compares with estimated UK RFNBO production costs of £5–12/kg at current electricity prices. Even on an exchange-rate-adjusted basis, this gap reflects real structural differences in input costs, grid infrastructure and regulatory complexity, not just bid strategy.

Topic 1 Prices: RFNBO Projects Are Clustering Below €1/kg

Four of the five Topic 1 projects bid between €0.57/kg and €0.98/kg — all well below the €4/kg ceiling and even below the €0.48/kg clearing price of the first EHB pilot auction. The Danish projects (NJK at €0.95/kg and ALBA at €0.97/kg) are large-scale RFNBO plays backed by dedicated renewable capacity, almost certainly wind. Denmark’s grid geography and the maturity of its offshore wind supply chain make it a natural home for low-cost RFNBO hydrogen, and these bid prices reflect that advantage.

The Greek and Spanish projects at €0.57/kg and €0.62/kg are smaller and may be leveraging high solar irradiance with low curtailment costs. The Austrian project at €0.98/kg, at just 5 MWe, looks more like an industrial anchor — probably serving a specific industrial offtaker in Austria’s chemical or steel complex — where the premium is almost certainly needed to make the economics stack on top of high Central European electricity costs.

The Maritime Premium: €3.48–3.49/kg is a Cost-of-Compliance Number

The two Norwegian maritime projects bid at €3.48/kg and €3.49/kg — more than three times the most expensive general-topic project. This is not a sign of poor economics; it is a sign of where maritime hydrogen sits on the cost curve today relative to fossil bunker fuel.

FuelEU Maritime, which entered into force in 2025, mandates a progressive reduction in GHG intensity for commercial vessels using EU ports. RFNBOs count double against the GHG intensity target until end-2033. But the baseline economics of liquefied hydrogen for shipping — cryogenic storage, boil-off losses, limited bunkering infrastructure, small volumes — remain challenging. The Norwegian projects are probably targeting small vessels or specific maritime corridors where the regulatory premium justifies the cost. At €3.48–3.49/kg, they are near the €4/kg ceiling but still competitive within their topic basket. Whether the underlying offtake structure is robust is a different question.

Oversubscription and Price Discovery

58 bids requesting €8.4 billion competed for €1.3 billion of EU budget — a ratio of roughly 6.5:1 on funding requested, with 49 projects not selected. The bids submitted in aggregate would have installed 4.3 GWe of electrolyser capacity. In the RFNBO general topic alone, 50 bids requested more than €7.3 billion.

This level of oversubscription is significant for two reasons. First, it demonstrates that developer appetite is genuine and broad, spanning 11 countries. Second — and more importantly — it generates a large, policy-relevant dataset of vetted bid prices, technology configurations, capacity levels and offtake structures that will inform how the Commission calibrates the next round, tightens additionality rules, and assesses whether complementary demand mandates are working. If bid prices continue falling while volume keeps rising, that is evidence that the cost gap is closing and that future support rounds can reduce the ceiling.

The IF24 Attrition Problem Has Not Gone Away

The second auction (IF24) resulted in only 6 of 15 initially selected projects reaching grant signature. The Commission allocated €992 million initially, but the final signed amount was just €270 million — a fraction of the available budget. The causes were structural: a demanding completion guarantee requirement (8% of total grant), difficulty securing bankable offtake agreements, and the mismatch between auction selection speed and the slower timelines of project finance.

IF25 has tightened maturity requirements. The financial close deadline is two and a half years from grant signature, with entry into operation within five years. Whether that is sufficient to prevent a repeat of IF24’s attrition rate depends on whether the broader enabling conditions have improved: power grid connections, permitting timelines, offtake market depth and lender appetite. For a detailed look at how infrastructure constraints can ground well-funded hydrogen programmes, see the note on UK Hydrogen Infrastructure.

What Are RFNBO Rules and Why Do They Matter So Much?

Renewable Fuels of Non-Biological Origin (RFNBOs) are defined under the Renewable Energy Directive as fuels produced from electricity that is additional, geographically correlated and temporally correlated with renewable generation. These three conditions — additionality, geographic correlation and temporal correlation — are the central cost and complexity drivers for most RFNBO hydrogen projects.

Additionality

Additionality requires that the renewable electricity used to produce RFNBO hydrogen comes from new capacity that would not have been built otherwise. Projects commissioned before 2028 are exempted from this requirement, which is why the first and second EHB auction winners enjoy a significant cost advantage over projects commissioned later, for whom the cost of developing dedicated new renewable capacity — wind, solar, or a combination — is fully embedded in the economics.

Temporal Correlation

Until 2030, RFNBO producers must demonstrate that the renewable electricity was generated within the same calendar month as the hydrogen was produced. After 2030, the requirement tightens to hourly matching. This is a material cost driver: hourly matching forces either very high-capacity renewable portfolios with battery storage, or much lower electrolyser utilisation — in either case, higher levelised cost. Projects that rely on monthly matching until 2030 and are bidding for support that runs ten years from entry into operation face a regulatory cliff in the middle of their support period.

Geographic Correlation

The electrolyser and the renewable electricity source must be in the same bidding zone or a connected bidding zone with equivalent or higher prices. This rules out, for example, a project in Central Europe claiming electricity from a remote offshore wind farm in the North Sea through a congested grid. It also makes projects on interconnected Scandinavian or Iberian grids structurally more attractive, which partly explains the concentration of low-bid projects in Denmark, Finland and Spain.

The low-carbon electrolytic hydrogen category introduced in IF25 Topic 2 bypasses the RFNBO rules in exchange for meeting a 70% GHG reduction threshold. This creates a two-tier market: RFNBO projects that comply with the full RED III additionality framework, and low-carbon projects that achieve comparable emissions savings through a cleaner grid rather than dedicated renewables. The €0.44/kg Cloudberry project exploits exactly this distinction.

The Regulatory Stack Driving Demand

The EU hydrogen auction mechanism does not exist in isolation. It sits inside a carefully layered set of demand mandates and sectoral regulations designed to create and sustain markets for the hydrogen it supports. Understanding those mandates is essential for evaluating whether IF25 winners can actually sell their molecules.

RED III: Binding Industrial and Transport Targets

The Renewable Energy Directive III (RED III) creates binding hydrogen demand through two pathways. For industry, 42% of hydrogen consumed from 2030 must be RFNBO; this rises to 60% by 2035. For transport, a 1% RFNBO sub-target applies within the overall 5.5% advanced biofuel and RFNBO sub-target by 2030. These are legally binding obligations, not indicative targets, and they form the core offtake rationale for most Topic 1 RFNBO projects.

FuelEU Maritime and RefuelEU Aviation

FuelEU Maritime mandates a progressive reduction in GHG intensity for vessels using EU ports, with RFNBOs counting double towards compliance until end-2033. If the shipping industry does not reach 1% RFNBO fuel share by 2031, a 2% mandatory floor kicks in by 2034. This is the primary regulatory driver for Topic 3.

RefuelEU Aviation requires EU airports to supply sustainable aviation fuel (SAF) with binding RFNBO sub-targets. The interaction between these sector mandates and the IF25 Topic 3 ring-fenced budget is direct: the Topic 3 basket exists because the economics of maritime and aviation RFNBO are structurally different from general industrial hydrogen, and blending them into a single undifferentiated basket would mean maritime and aviation projects are simply never competitive.

The Carbon Price as the Backstop

The EU ETS carbon price is the long-term backstop for hydrogen demand. If the carbon price rises sufficiently, fossil hydrogen becomes uncompetitive and the premium required from the auction falls to zero. The auction mechanism is explicitly designed as a transitional instrument. Its purpose is to accelerate the first wave of scale projects before the carbon price is high enough to do the job unaided. Projects that understand this — and design their offtake structures with one eye on the trajectory of the carbon price — are better positioned for long-term commercial viability.

Project Finance Implications

The production premium structure — payments only after commissioning and only on certified production — creates a specific risk profile that differs materially from capex grants or CfD-style revenue guarantees. Understanding this matters for developers trying to finance these projects through project finance structures.

Revenue Stack, Not Single Subsidy

The auction premium sits on top of whatever price the offtaker pays for hydrogen. For a project with a €0.57/kg bid price, the offtaker price plus the premium needs to cover the full levelised cost of hydrogen including financing. With European green hydrogen currently priced around €7–8/kg at production cost (before subsidies), and grey hydrogen roughly €1–2/kg, the premium provides an important contribution but is not the whole answer — the offtaker also needs to pay a meaningful market price for the molecule. Long-term offtake contracts, or contracts for difference with regulated industrial buyers, are therefore not optional extras — they are the prerequisite for bankability.

Completion Guarantee and Lender Risk

IF25 projects must provide a completion guarantee equivalent to a defined percentage of the grant amount from an approved financial institution. In IF24, this requirement — combined with high interest rates and uncertain offtake markets — contributed directly to project withdrawals. IF25 maintains a comparable structure. For project finance lenders, the completion guarantee sits alongside grid connection risk, permitting risk and technology risk. In markets where grid connection timelines are uncertain (as they are across most of Europe), the five-year entry-into-operation deadline creates a hard backstop that lenders must price.

Power Price Exposure

The premium is fixed per kilogram of hydrogen. The underlying cost of production — driven primarily by electricity price and electrolyser utilisation — is not hedged by the premium. A project that assumed €50/MWh wind power at FID but finds itself exposed to €80/MWh grid costs post-commissioning will find that the fixed premium does not compensate for the shortfall. This pushes developers towards either fixed-price long-term PPAs (which are increasingly difficult to source in competitive renewable markets) or towards sites with access to genuinely low-cost dedicated renewable capacity — which is exactly what the geographic correlation rules are designed to encourage.

For more on the investment landscape in hydrogen at this moment, see the analysis at Hydrogen Investment Opportunity 2026.

Implications for Entrepreneurs, Investors and Policymakers

For Entrepreneurs: IF25 Is a Filter, Not a Grant Call

The IF25 European hydrogen auction does not reward the best presentation or the most compelling technology narrative. It rewards teams that can stitch together permitting, grid connection, power procurement, RFNBO certification and bankable offtake into a coherent project, at a bid price that wins in competition with other developers facing the same challenge. The auction mechanism is a market test, not a funding application.

Projects that are still conceptual — without land rights, grid pre-agreements or preliminary offtake discussions — should not be entering IF26 expecting to rely on the premium to make impossible economics possible. Projects that are genuinely well-structured, with realistic power procurement and committed offtakers in hard-to-abate sectors, have a clear path to grant agreement and, potentially, to long-term viability.

Startups without the balance sheet to develop full projects should be positioning as indispensable technology and service providers to auction-backed platforms: electrolyser optimisation software, RFNBO certification systems, PPA structuring, and grid integration services are all structurally in demand.

For Investors: Understand the Risk Bifurcation

The bid price range of €0.44/kg to €3.49/kg across IF25 winners is not a sign of a single homogeneous market. It reflects three structurally different investment profiles: low-carbon electrolytic hydrogen at scale in low-carbon-grid countries (Cloudberry type), mid-scale RFNBO projects in high-renewable-endowment locations (the Danish and Greek projects), and small-scale high-premium projects serving niche regulatory mandates (maritime in Norway).

For each profile, the key risks differ. Cloudberry-type investments are exposed to grid carbon intensity trends and policy durability of the low-carbon electrolytic hydrogen category. Mid-scale RFNBO projects are exposed to temporal correlation rule tightening post-2030 and renewable power price volatility. Maritime projects are exposed to regulatory enforcement of FuelEU Maritime and to offtaker creditworthiness in shipping, which is notoriously cyclical.

Production premiums of up to €4/kg for ten years are meaningful, but they sit inside a wider set of risks that need to be priced, not assumed away.

For Policymakers: The AaaS Model Is Working; Delivery Is the Next Test

The Auction-as-a-Service mechanism is demonstrably working as a tool for harmonising national and European support into a single competitive process. Germany’s €1.3 billion and Spain’s €440 million commitments to IF25 are direct evidence that Member States prefer to use an EU-run, independently evaluated auction rather than build parallel national structures.

The policy failure risk has shifted from design to implementation. Nine projects must now reach financial close within 30 months and enter operation within five years. The Commission and CINEA need to ensure that grid connection queues, permitting frameworks and the administrative demands of certification do not create bottlenecks that convert a successful auction selection into another round of project attrition. For context on how infrastructure constraints can ground well-intentioned hydrogen policy, the UK’s HyHAUL experience is instructive.

What Is Industry Still Getting Wrong?

Treating the Auction as a Revenue Guarantee

The premium is a fixed payment per certified kilogram. It is not a floor on total project revenue, not a guarantee of offtake volume, and not a hedge against power price movements. Projects that model the premium as a certainty and treat the rest of the revenue stack as residual will find themselves in trouble when electricity costs move, when electrolyser availability falls below target, or when certification costs prove higher than budgeted.

Underestimating Offtake Complexity

The auction requires credible evidence of preliminary offtake agreements. But “preliminary agreement” and “bankable long-term offtake contract” are not the same thing. In the second auction, a significant factor in project withdrawals was the inability to convert preliminary agreements into contracts that satisfied project finance lenders. RED III mandates create a regulatory imperative for industrial buyers to source RFNBO hydrogen, but the timing and structure of those mandates do not automatically translate into bankable offtake — especially for buyers who are themselves navigating capital allocation decisions under high energy costs and uncertain industrial policy.

Ignoring the Certification Cost Burden

RFNBO and low-carbon hydrogen certification is not a box-ticking exercise. It requires ongoing metering, data systems, third-party verification and interaction with national hydrogen registries — all of which carry real cost and operational overhead. These costs are particularly material for smaller projects (such as the 5 MWe Austrian project, which will generate proportionally high certification overhead relative to volume). Teams that have not built certification cost into their levelised cost of hydrogen models from day one are operating with optimistic economics.

Assuming RFNBO Rules Stay Stable

The shift from monthly to hourly temporal correlation in 2030 is known and quantifiable. What is less certain is how national regulators implement additionality and geographic correlation under their transpositions of RED III, and how the European Commission adjusts rules as it accumulates data from the auction programme. Projects with ten-year support periods starting in 2028–2029 will be operating under the post-2030 regime for most of their support life. That risk needs to be embedded in project economics, not treated as a future problem.

The auction also demonstrates how a commercialisation framework can convert policy ambition into investable price discovery. The controlling barrier is regulatory alignment: projects must combine subsidy bids, RFNBO compliance, offtake contracts and lender requirements into one durable revenue model. A low bid is useful evidence, but it does not remove delivery risk. The commercially strongest projects will be those whose regulatory obligations support customer demand and financeability rather than remaining a separate compliance exercise.

Closing Insight

The IF25 results confirm that the European hydrogen auction is functioning as a price discovery mechanism. Clearing prices far below the €4/kg ceiling, a single bid at €0.44/kg, and a 6.5:1 oversubscription ratio are not evidence of a market awash with cheap hydrogen — they are evidence that, in the right locations with the right grid characteristics, serious developers can structure credible projects that need only a modest premium to be commercially viable.

The harder test is delivery. IF24’s attrition rate showed that winning an auction is not the same as building a hydrogen plant. The Commission, CINEA and Member States will be watching the nine IF25 projects closely through the GAP process, financial close, and grid connection phases. If the majority reach commissioning, IF25 will be the round where the EU hydrogen auction mechanism matures from experiment to infrastructure. If attrition repeats, the redesign conversation will be about delivery conditions, not bid mechanics.

The question for the next round is not “how low can bids go?” It is “how many of the projects that win actually get built?”