The Netherlands is currently grappling with a significant disconnect between its ambitious national hydrogen targets and the economic realities of green energy production, as evidenced by a series of project cancellations and ballooning infrastructure costs. In 2022, the Dutch government signaled its commitment to becoming a European hydrogen hub by awarding €783.5 million in subsidies to seven pioneering green hydrogen projects. These initiatives were intended to deliver a combined 1,150 megawatts (MW) of electrolysis capacity, forming the backbone of a new decarbonized industrial economy. However, four years after these initial awards, the landscape has shifted dramatically: four of those seven projects, representing 550 MW of capacity, have been cancelled, and not a single one of the original seven is currently in operation.
This stagnation comes at a critical juncture for the Dutch energy transition. While the government has only disbursed roughly €150 million of the allocated funds so far—mitigating immediate losses to the taxpayer—the failure of these projects to reach the operational stage raises fundamental questions about the viability of current policy frameworks. Despite these setbacks, the government remains committed to its original path, with another €780 million reserved for a future subsidy round and plans for a national hydrogen pipeline network continuing apace.
A Chronology of Declining Expectations
The trajectory of the Dutch hydrogen strategy reveals a pattern of early optimism followed by a steady encounter with technical and financial hurdles. When the initial subsidies were granted in 2022, the prevailing sentiment was that renewable hydrogen would rapidly reach price parity with fossil-fuel-derived "grey" hydrogen.
In 2020, the Netherlands launched its National Hydrogen Strategy, positioning the country to leverage its North Sea wind potential and its existing gas infrastructure. By 2022, the first major subsidy tranche was intended to kickstart the market. However, by late 2023 and throughout 2024, the global energy landscape was upended by high interest rates, supply chain disruptions for electrolyser components, and volatile electricity prices.
By November 2, 2026, parliamentary answers confirmed a sobering reality: the government could no longer predict when electrolytic hydrogen would become commercially viable without permanent state support. This was followed by a December 2025 report from the Netherlands Court of Audit, which warned that the construction of a sustainable hydrogen network was becoming increasingly uncertain. The timeline suggests that while the policy was built on 2020 forecasts, the implementation is failing to adapt to the 2026 economic environment.
The Economic Arithmetic of Electrolysis
At the heart of the crisis is the cost of production. Original government forecasts were predicated on the assumption that renewable hydrogen would cost approximately €2 per kilogram by 2030. To reach this figure, several optimistic variables had to align, most notably the cost of renewable electricity.
The physics of hydrogen production are uncompromising. Producing one kilogram of hydrogen via electrolysis typically requires between 50 and 55 kilowatt-hours (kWh) of electricity. If an industrial facility were to secure electricity at a rate of €50 per megawatt-hour (MWh)—a price significantly lower than current average non-household industrial rates in Europe—the power cost alone would range from €2.50 to €2.75 per kilogram of hydrogen. This calculation excludes capital recovery for the expensive electrolysers, maintenance costs, water treatment requirements, compression for transport, and delivery fees.
While project developers can lower energy costs by purchasing electricity only during "off-peak" hours when wind and solar production are high, this strategy creates a secondary financial problem. Running an electrolyser only during cheap hours reduces its utilization rate, or "load factor." When an expensive piece of industrial machinery sits idle for a large portion of the day, the capital cost per unit of hydrogen produced rises sharply. This catch-22—choosing between high energy costs or high capital costs—has rendered the €2/kg target nearly impossible to achieve under current market conditions.
Infrastructure and the "Death Spiral" Risk
The Dutch strategy relies heavily on the development of a national hydrogen "backbone"—a series of pipelines managed by Gasunie and its subsidiary, Hynetwork Services. This infrastructure is intended to connect offshore wind power and import terminals at the Port of Rotterdam to industrial clusters in the hinterland.
However, the economics of this network are deteriorating. The Netherlands Court of Audit found that estimated investment costs for the backbone have surged from an initial €1.5 billion to €3.8 billion. Furthermore, Gasunie/Hynetwork Services has projected startup losses of up to €2.5 billion, even after accounting for a €750 million government grant.
This creates a significant risk of an infrastructure "death spiral." To recover the massive investment costs, the network operator must charge tariffs to its users. As the cost of the network increases and the projected demand for hydrogen shrinks, the tariffs per unit of hydrogen must rise. Higher tariffs make hydrogen even less competitive for industrial customers, leading to further cancellations and a further reduction in the customer base. This cycle threatens to leave the Dutch state with a multi-billion-euro "stranded asset" if the predicted market fails to materialize.
Shifting Demand and Industrial Realities
While the government continues to push for high production volumes, its own energy planning departments have begun to revise demand expectations downward. In September 2025, updated energy planning documents significantly reduced the role of hydrogen in building heat and electricity generation. Earlier visions of hydrogen-heated homes have largely been replaced by the realization that industrial heat pumps and district heating are more efficient and cost-effective.
In the industrial sector, the outlook is also changing. Heavy industries such as chemical manufacturing, steel processing, and refining are the primary intended users of green hydrogen. However, these industries are exploring alternative decarbonization routes that do not involve expensive domestic hydrogen production:
- Direct Electrification: Many industrial processes that require heat can be served more efficiently by high-temperature heat pumps or electric furnaces, bypassing the energy losses inherent in converting electricity to hydrogen and back again.
- Imported Feedstocks: Rather than producing green hydrogen domestically, Dutch industries may find it cheaper to import hydrogen-dense carriers like green ammonia from regions with more abundant and consistent renewable energy, such as North Africa, Chile, or Australia.
- Refining Contraction: As the transition to electric vehicles accelerates, the demand for petroleum products declines. Since refineries are major consumers of hydrogen for desulfurization and cracking, a shrinking refinery sector naturally leads to lower hydrogen demand.
Official Responses and Political Implications
The Dutch government’s response to these challenges has been a mix of persistence and caution. In parliamentary briefings, officials have acknowledged the cancellations but argued that "first-mover" risks are an inherent part of developing a new energy economy. They maintain that the subsidies are necessary to de-risk projects that would otherwise never reach a Final Investment Decision (FID).
However, critics within the parliament and the Court of Audit argue that the government is "bargaining" with reality. By committing to another €780 million subsidy round, the state may be doubling down on a technology-specific target rather than a broader decarbonization goal. There is growing pressure for the government to adopt a more "technology-neutral" approach that supports any method of reducing carbon emissions, rather than mandating the use of green hydrogen specifically.
The industrial sector has also voiced concerns. While trade groups generally support subsidies, they have warned that "obligations" to buy renewable hydrogen—currently being considered by the government—could undermine the competitiveness of Dutch industry if the costs are significantly higher than global benchmarks.
Analysis of Broader Impacts
The struggles of the Dutch hydrogen strategy serve as a bellwether for the broader European Union energy transition. The EU has set a target of producing 10 million tonnes and importing 10 million tonnes of renewable hydrogen by 2030 under the REPowerEU plan. The Dutch experience suggests that these targets may be overly optimistic and fail to account for the fundamental physics and economics of the energy carrier.
For the Netherlands, the stakes are particularly high. The country’s industrial clusters, particularly in Rotterdam, Moerdijk, and Terneuzen, are vital to the national economy. If the government’s industrial strategy remains tethered to high hydrogen volumes that the market cannot afford, it risks losing these industries to regions with lower energy costs.
A more resilient industrial strategy might involve focusing on the high-value manufacturing stages of the supply chain while accepting that the "bulk" production of green molecules may happen elsewhere. This would involve investing in port infrastructure for imports and direct electrical grids for domestic factories, rather than focusing exclusively on domestic electrolysis.
Conclusion: A Call for Strategic Evaluation
As the Netherlands prepares for its next round of hydrogen subsidies, it faces a landscape vastly different from that of 2022. The evidence of the past four years—cancelled projects, rising infrastructure costs, and shrinking demand—cannot be ignored. The government now has a critical opportunity to re-evaluate its industrial strategy before committing another large tranche of public funds.
The path forward requires a focus on the actual products being made and the most cost-effective routes to decarbonizing them. This may mean a smaller, more targeted hydrogen market focused strictly on "hard-to-abate" sectors like chemical feedstocks, rather than a broad-based hydrogen economy. Without such a pivot, there is a mounting risk that the Netherlands will spend the next decade funding yesterday’s forecasts at the expense of tomorrow’s economic stability. The challenge is no longer just a matter of engineering, but of aligning public policy with the harsh realities of the global energy market.
