IN Brief:
- Ore Energy has signed an agreement with Budget Thuis to deploy up to 1,000MWh of iron-air battery storage in the Netherlands.
- The first 400MWh phase is planned for delivery in 2028, with discharge durations configurable from 24 to 100 hours.
- The project adds momentum to Europe’s long-duration storage market as grid operators manage curtailment, volatility, and renewable intermittency.
Ore Energy has signed an agreement with Dutch utility supplier Budget Thuis to deploy up to 1,000MWh of multi-day iron-air battery storage in the Netherlands.
The first phase covers 400MWh and is planned for delivery in 2028. The wider agreement covers up to 1GWh, giving the Amsterdam-based storage company one of the more substantial European commercial pipelines for iron-air storage so far. The system is designed for discharge durations between 24 and 100 hours, placing it in the long-duration category rather than the short-cycle battery market dominated by lithium-ion systems.
Ore Energy’s technology uses iron, water, and air as its core chemistry. Its storage units are configured at megawatt-hour scale in 40-foot enclosures, giving the system a modular form that can be deployed at utility sites without relying on the same cell chemistry or operating profile as conventional lithium-ion batteries. The company is targeting wind-heavy grids where surplus generation, curtailment, and extended low-output periods are becoming more prominent operational concerns.
The Netherlands provides a demanding test environment for that type of asset. Renewable generation has grown quickly, while grid congestion and connection scarcity have become persistent constraints. Periods of high wind output can leave networks with more electricity than they can absorb, while longer low-wind periods can expose the limits of short-duration storage. Multi-day systems are designed to sit between short-cycle batteries and firm generation, shifting energy across longer periods than conventional grid batteries usually cover.
Iron-air storage does not replace lithium-ion batteries. Short-duration lithium-ion systems remain well suited to fast response, frequency services, intraday trading, and rapid cycling. Multi-day storage is aimed at a different system requirement: absorbing larger volumes of electricity over extended periods and returning it when renewable output falls for longer than a few hours. As wind and solar penetration rises, those functions become complementary rather than competitive.
The first 400MWh phase will test more than battery chemistry. A long-duration storage asset has to manage power conversion, grid-code compliance, thermal conditions, site footprint, controls, protection, safety systems, degradation, dispatch optimisation, and maintenance access over long operational cycles. Its value will depend on how well it is integrated into market operation and local network conditions, not only on nameplate energy capacity.
European policy discussions around long-duration storage as strategic infrastructure have accelerated as power systems absorb more weather-dependent generation. Fast batteries can balance seconds and hours, but adequacy, resilience, and curtailment reduction increasingly require storage that can operate across days. The Ore Energy agreement gives that discussion a larger commercial deployment pathway.
The project also reflects a wider effort to diversify storage supply chains. Lithium-ion systems are mature, bankable, and increasingly competitive, but they are exposed to global cell manufacturing concentration, materials markets, and competing demand from electric vehicles. Iron-air systems use more abundant materials, which may offer a route to lower-cost long-duration storage if performance, safety, efficiency, and project economics are proven at scale.
Commercial design remains the harder question. Long-duration storage is not always rewarded by markets built around fast cycling and short-duration services. A 100-hour asset needs revenue routes that value avoided curtailment, system adequacy, congestion relief, resilience, and the displacement of fossil generation during longer renewable shortfalls. Without those signals, the technology can be useful to the system while remaining difficult to finance.
Grid access will also shape the outcome. Storage projects need connection capacity, but their system value depends heavily on location. A multi-day battery connected near constrained renewable generation can absorb power that might otherwise be curtailed. The same asset in a poorly chosen location may face limited charging opportunities or weak price signals. Planning, connection allocation, and market dispatch therefore become part of the engineering case.
For the Dutch electricity system, the Budget Thuis agreement adds a new form of flexibility to a grid already under pressure from electrification, decentralised generation, and congestion. For Europe, it provides a larger-scale reference point for iron-air technology as the storage market broadens beyond short-duration lithium-ion batteries.
The planned 2028 first phase will be watched closely because it combines storage chemistry, utility procurement, grid integration, and long-duration market design in one project. If it performs commercially and technically, iron-air storage could become part of a more diverse European storage mix alongside lithium-ion batteries, pumped hydro, flow batteries, thermal storage, compressed-air systems, and other emerging technologies.
