Germany risks €45bn in public costs due to overestimated hydrogen demand

Germany commits €20 billion to hydrogen pipeline network

Germany has pushed ahead with plans to build a 9,000 kilometre hydrogen pipeline network by 2032, despite growing concerns that demand projections may be wildly optimistic. The country’s Federal Network Agency locked in a tariff structure in July 2025 that guarantees revenue for operators until 2055, regardless of how much hydrogen actually flows through the pipes.

Research from the Institute for Energy Economics and Financial Analysis suggests this mismatch between infrastructure capacity and realistic demand could leave German taxpayers exposed to losses of up to €45 billion. For UK businesses watching Europe’s energy transition, this case offers important lessons about the risks of overcommitting to unproven technologies before markets develop.

The European Commission approved €3 billion in German state aid for the project in June 2024. However, independent analysis indicates that actual hydrogen consumption may reach less than 20 terawatt hours per year by 2030, compared to official forecasts of 70 to 110 terawatt hours. That would leave between 70% and 90% of the network’s capacity sitting idle.

Germany launched its National Hydrogen Strategy in 2020, positioning green hydrogen as essential for decarbonizing sectors like steel production, chemicals manufacturing, and heavy transport. The Wasserstoffkernnetz, as the core network is known, will transport hydrogen from import terminals and domestic production sites to industrial consumers across the country.

EU approval and guaranteed revenue model create long term commitments

In June 2024, the European Commission cleared Germany’s €3 billion state aid package under EU competition rules. The Commission stated the funding was necessary for advancing the energy transition, concluding it would not unduly distort competition in the Single Market. This approval allowed construction to proceed on schedule for 2025.

The Federal Network Agency then set a ramp up tariff of €25 per kilowatt hour per hour per year on 14 July 2025. Critically, this tariff remains fixed until 2055, with adjustments only for inflation. The structure guarantees returns for network operators regardless of utilization levels, effectively transferring demand risk away from private investors onto consumers and taxpayers.

Construction tenders went to a consortium including Open Grid Europe and Gascade, with the full network scheduled to become operational by 2032. Total costs for the core network range between €20 billion and €24 billion, though broader hydrogen infrastructure plans could push spending above €45 billion by 2040.

The tariff mechanism creates planning certainty for investors, which was a key objective for German policymakers. Nevertheless, it also means that if hydrogen demand fails to materialize as projected, the gap between infrastructure costs and usage revenue gets covered through higher energy bills for German households and businesses.

Independent research questions official demand forecasts

A July 2025 report from the Institute for Energy Economics and Financial Analysis examined the Bundesnetzagentur’s demand projections and concluded they significantly overestimate likely hydrogen consumption. Using the agency’s own data, researchers modeled scenarios where demand reaches only 50 terawatt hours per year by 2040. Consequently, around 60% of the network’s capacity would remain unused.

Even this projection may prove optimistic. Recent industrial trends suggest hydrogen demand could fall substantially below 50 terawatt hours. A 2025 study from Fraunhofer ISE revised industrial hydrogen requirements downward by 20% to 30%, citing efficiency improvements in manufacturing processes and faster than expected adoption of direct electrification alternatives.

Germany’s hydrogen strategy assumes the country will import roughly 70% of its hydrogen needs by 2030. However, global supply chains remain uncertain. Australia, the United States, and Middle Eastern producers are competing for European contracts, and shipping costs continue to make imported green hydrogen expensive compared to domestic fossil fuel alternatives.

No major industrial offtake agreements have been announced that would absorb the network’s planned capacity. Meanwhile, sectors previously identified as key hydrogen consumers are increasingly exploring battery electric solutions or process redesigns that reduce energy intensity altogether.

How a 30 year tariff lock affects German households and industry

The 2055 tariff commitment means German energy consumers will pay for this infrastructure whether or not it gets used. If utilization falls below 30% to 40%, the fixed costs of maintaining a largely empty pipeline network get socialized through electricity bills. Analysis from Agora Energiewende projects this could add €50 to €100 per year to household energy costs.

For German manufacturers, particularly in energy intensive sectors, the tariff creates a different problem. Companies that might otherwise invest in hydrogen technologies face uncertainty about long term costs. If the network remains underutilized, hydrogen prices could stay high due to insufficient scale economies, making alternatives like electrification more attractive financially.

This dynamic could become self reinforcing. Higher costs deter industrial adoption, which keeps utilization low, which maintains high unit costs, which further discourages adoption. The result would be a network built for a hydrogen economy that never fully materializes, leaving taxpayers covering the shortfall for three decades.

For businesses outside Germany, this matters because similar hydrogen infrastructure plans are under consideration across Europe. The UK government has supported hydrogen blending trials and is evaluating network investments. Netherlands is developing its own hydrogen backbone. If Germany’s approach results in significant stranded assets, it may prompt other countries to take a more cautious, demand led approach to infrastructure development.

Comparing Germany’s hydrogen bet with past energy infrastructure decisions

Germany has previous experience with energy infrastructure that became underutilized following policy shifts. The country’s Energiewende, its transition away from nuclear power and toward renewables, left an estimated €10 billion to €15 billion in stranded natural gas assets. Pipelines and storage facilities built to bridge the transition saw lower than expected demand as renewables scaled faster than anticipated.

The hydrogen network differs in scale and longevity. The 2055 tariff timeframe is considerably longer than previous infrastructure commitments. Moreover, hydrogen technology is less mature than natural gas was during the Energiewende, adding uncertainty about both supply and demand development.

Government modeling suggests potential benefits if demand materializes. Officials project the hydrogen economy could create 100,000 jobs and enable 20% to 30% emissions reductions in steel and chemicals by 2045. These figures assume, however, that green hydrogen becomes cost competitive with current production methods, which requires both cheaper renewable electricity and substantial scale.

The European Union’s Hydrogen Accelerator Act, introduced in 2024, targets 20 million tonnes of annual hydrogen imports across member states. Germany’s network is designed to be a central hub in this system. Nevertheless, the Act does not create demand. It establishes targets and regulatory frameworks, leaving market development to industry and consumers.

Five key points about Germany’s hydrogen infrastructure program

• Germany will build a 9,040 kilometre hydrogen pipeline network by 2032, with total public investment between €20 billion and €24 billion for the core network alone.
• The Federal Network Agency set a fixed tariff of €25 per kilowatt hour per hour per year in July 2025, guaranteed until 2055 with only inflation adjustments, transferring demand risk to consumers.
• Independent research projects actual hydrogen demand may reach less than 20 terawatt hours per year by 2030, compared to official forecasts of 70 to 110 terawatt hours, potentially leaving 70% to 90% of capacity unused.
• If utilization falls below 30%, German households could face €50 to €100 in additional annual energy costs to cover fixed infrastructure expenses, according to analysis from Agora Energiewende.
• Total public exposure could reach €45 billion if the network remains significantly underutilized through 2055, creating Europe’s largest stranded energy asset and affecting energy transition strategies across the UK and other European countries.

What UK businesses should consider about hydrogen infrastructure timing

Germany’s experience highlights the risks of building large scale infrastructure ahead of proven demand. For UK businesses evaluating their own decarbonization pathways, this suggests caution around early commitments to hydrogen dependent processes, particularly where electric alternatives exist.

Companies tendering for public sector contracts increasingly face requirements to demonstrate net zero plans. Our net zero program for carbon reporting compliance helps businesses develop credible strategies that align with PPN 06/21 requirements without overcommitting to specific technologies before costs and availability become clear.

Several sectors warrant particular attention. Steel and chemicals manufacturers may find hydrogen essential for certain processes, but the German case suggests waiting for clearer price signals before locking in long term supply contracts. Transport operators should compare total cost of ownership for hydrogen versus battery electric vehicles over realistic timeframes, rather than relying on projected hydrogen price reductions that may not materialize.

Supply chain implications matter too. Businesses that depend on German manufacturing may see cost increases if the country’s hydrogen bet drives up energy prices. Meanwhile, procurement teams should scrutinize supplier decarbonization claims that rely heavily on future hydrogen availability, as supply constraints could delay or increase costs of achieving stated emissions reductions.

The 2055 timeframe is particularly relevant for capital investment decisions. Equipment purchased today with 15 to 20 year lifespans will need retrofitting or replacement if hydrogen infrastructure fails to develop as planned. Therefore, flexibility should be a key criterion in technology selection, favoring solutions that can adapt to multiple energy scenarios.

From a policy perspective, the German situation demonstrates the tension between first mover advantage and prudent resource allocation. The UK government faces similar choices around hydrogen infrastructure investment. Businesses engaging with policy consultations should emphasize the importance of demand led development, where infrastructure scales in response to actual consumption rather than projected targets.

Learning from Europe’s largest energy infrastructure gamble

Germany’s hydrogen network represents the most ambitious bet any European country has made on hydrogen’s role in decarbonization. The scale of potential losses, up to €45 billion in public funds, makes this a critical test case for energy transition financing across the continent.

For businesses, the key lesson is about timing and flexibility. Technologies that seem essential today may become obsolete as alternatives improve or as policy priorities shift. Consequently, investment decisions should account for multiple scenarios, particularly when committing to infrastructure with multi decade lifespans.

The fixed tariff structure until 2055 shows how political decisions can lock in costs long after the rationale changes. UK businesses should monitor whether similar long term commitments emerge in domestic energy policy, as these create risks that extend well beyond normal planning horizons.

Ultimately, Germany’s hydrogen infrastructure may prove successful if global hydrogen markets develop as officials hope. However, current evidence suggests demand will fall well short of the network’s capacity for many years, if not decades. That gap will be filled by taxpayer subsidies and higher consumer energy costs, creating a cautionary tale about building transformative infrastructure before the underlying market exists.

Further information on hydrogen policy and infrastructure

The European Commission’s state aid approval decision provides details on the legal framework supporting Germany’s hydrogen network funding.

Germany’s Federal Network Agency published its tariff methodology and justification in July 2025, explaining the 2055 timeframe and risk allocation approach.

The Institute for Energy Economics and Financial Analysis released its analysis of demand projections and fiscal risks in July 2025, providing the €45 billion cost estimate.

For businesses assessing their own hydrogen strategies, the SBS compliance team can help evaluate technology options against regulatory requirements and market realities.