Summary
- The guide examines where hydrogen could be available to European data centres, when supply may develop, and its likely production costs.
- Europe had 677MW of operating electrolyser capacity in July 2026, compared with 37.6GW announced for 2030.
- The authors recommend coordinated development of hydrogen, renewable generation, storage, and computing infrastructure, while acknowledging that near-term use remains largely experimental.
Hydrogen Europe and the Net Zero Innovation Hub for Data Centers have published guidance examining how hydrogen could supply electricity to European data centres, identifying fuel availability, infrastructure development, and cost as major barriers to wider adoption.
The guide, Hydrogen Infrastructure for Europe’s Data Centres, addresses three practical questions: when hydrogen may become available, where suitable infrastructure is developing, and how much the fuel could cost. It recommends coordinating the development of data centres with hydrogen production, renewable generation, and energy storage.
The organisations say hydrogen power generation has been demonstrated at megawatt scale, including a 3MW test undertaken with INNIO in April 2026. Microsoft, Google, and Data4 participated as technical observers during that exercise, which used data centre load profiles rather than supplying a confirmed commercial campus.
Commercial deployment remains limited. The guide records 677MW of operating electrolyser capacity in Europe as of July 2026, against 37.6GW of announced capacity targeted for 2030. The announced pipeline is substantially larger than the infrastructure currently operating.
Electrolysers consume electricity to produce hydrogen. Their capacity cannot be equated with generating capacity available to a data centre, because hydrogen must subsequently be stored or delivered and converted into electricity using suitable generating equipment.
The full process involves losses and operating costs at each stage. A development therefore needs evidence about fuel production, transport, storage, power conversion, and site operation before the economics of hydrogen supply can be assessed.
Supply depends on location
The guide identifies Germany, the Netherlands, and Belgium as markets where hydrogen infrastructure is comparatively advanced. Other locations may initially need to rely on hydrogen transported by road or produced close to the data centre.
Hydrogen supply requires infrastructure beyond the generator itself. A site dependent on delivered fuel must provide appropriate unloading and storage facilities, with arrangements for replenishment, inspection, safety, and continuity of supply.
On-site electrolysis offers a different configuration, but introduces additional electricity consumption, water requirements, production equipment, and operating controls. Producing hydrogen locally does not remove the need for sufficient energy to operate the electrolysers.
For electricity generation during a grid interruption, stored hydrogen must be available in sufficient quantity for the intended duration of operation. That requirement depends on the generating equipment’s fuel consumption and the electrical load that it must support.
The commercial distinction between short-duration backup and prolonged or continuous generation is significant. A system that runs only occasionally may be assessed differently from one expected to deliver electricity for substantial periods every year.
Hydrogen Europe estimates that renewable hydrogen costs approximately €4–€14 per kilogram to produce. The guide also reports an average EU production cost of €7.1/kg in 2025 under the strictest renewable fuel rules.
Those figures are not delivered prices for individual data centres. Transport, storage, financing, utilisation, and the equipment required for electricity generation can increase the effective cost of using hydrogen at a particular site.
Integrated energy systems
The organisations propose developing digital energy hubs in which data centres, hydrogen production, renewable generation, batteries, and electricity network connections are planned together. The proposed configuration is intended to make better use of local energy assets and provide additional flexibility.
Renewable electricity could be used directly when available, stored in batteries for later use, or converted into hydrogen where production and storage arrangements make that economically viable. The selection between those options depends on the intended operating profile and the value of the energy at different times.
Batteries can respond rapidly to changes in electrical demand, but their energy capacity limits the duration of supply. Hydrogen may offer a different storage duration, although it requires more complex fuel infrastructure and incurs conversion losses.
Microgrid controls can coordinate multiple energy sources and electrical loads within a defined system. Their effectiveness depends on electrical protection, operating permissions, control settings, and the ability to maintain suitable supply conditions for connected computing equipment.
Hydrogen generation may reduce reliance on a conventional utility connection in some configurations, but it does not automatically eliminate the need for network access or resolve every regulatory constraint. Local generation may itself require planning consent, environmental permissions, and supporting infrastructure.
The guide argues that data centre demand could provide hydrogen producers with long-term customers, improving the commercial basis for investment. Such arrangements would still require agreements covering fuel quantities, prices, availability, and responsibilities if supply is interrupted.
Alberto Ravagni, chief executive of the Net Zero Innovation Hub for Data Centers, has identified infrastructure availability and pricing as essential information for organisations considering hydrogen-powered facilities.
The guide presents hydrogen as one possible component of future data centre energy systems rather than a universally applicable substitute for electricity networks. Projects reaching final investment decisions by 2027 could support larger commitments, but the extent of commercial use will depend on the delivery of fuel infrastructure and the economics established for individual sites.
