Southeast Europe is emerging as one of Europe’s most attractive electricity-storage markets as intraday price spreads widen. The commercial case for batteries is supported by rapid solar deployment, constrained transmission networks, volatile hydropower output and continued reliance on thermal generation during evening demand peaks.
ENTSO-E’s latest value indicators place Hungary at the top of Europe’s storage market. Greece follows at €798/MW, with Bulgaria at €797/MW and Romania at €792/MW. Croatia is listed at €692/MW and Slovenia at €668/MW, compared with Italy at €406/MW, Sweden at €326/MW and Norway at €215/MW.
The indicators reflect the average spread between the eight lowest-priced and eight highest-priced hours of each day. They are not presented as annual revenue forecasts, but they show where energy-arbitrage conditions are strongest. The regional premium is linked to frequent low-price periods during solar-heavy hours, followed by sharp price recovery when photovoltaic output declines.
EU funding and corporate plans for standalone storage in Romania
Romania is moving to convert volatility into an investable asset class. The country received €636.9 million in the latest EU Modernisation Fund allocation, including support for standalone storage.
Nova Power & Gas, part of E-INFRA Group, has also announced a €1 billion investment programme through 2029. The plan covers generation, batteries and integrated energy infrastructure.
Solar growth in Greece coincides with lower capture value
Greece is another market where storage is positioned to respond to changing solar economics. Solar capacity increased from 8.82 GW at the end of 2024 to 11.5 GW at the end of 2025.
The reported solar capture value fell to €43/MWh, described as the lowest among the covered Southeast European markets. This decline is cited alongside battery storage’s role in protecting the value of new photovoltaic projects.
Modelling requirements for lender-grade battery revenue
The investment case requires more than applying a theoretical price spread to available capacity. A lender-grade approach must incorporate round-trip efficiency, degradation, auxiliary consumption, grid charges and state-of-charge restrictions.
The same model also needs cycling warranties and potential merchant-price compression included in assumptions. Revenues from balancing, ancillary services, congestion management and capacity mechanisms should be modelled separately from day-ahead arbitrage.
CAPEX ranges and market access considerations for BESS projects
A typical regional two-hour BESS may require installed CAPEX of approximately €250,000–€400,000 per MW. The figure depends on project duration, grid-connection works, fire-safety requirements and the selected integrator.
Four-hour systems require a larger capital envelope but can provide better protection against solar oversupply and extended evening price peaks. Projects are described as more likely to secure higher returns when they obtain grid access early and combine multiple revenue streams.
Pure merchant batteries remain exposed to spread compression as additional storage capacity enters the market. Co-located systems can help protect solar capture prices, while independently connected batteries can operate more freely across wholesale and balancing markets.
Grid access, studies and connection agreements for financial close
Southeast Europe’s battery opportunity is described as involving grid constraints and market design alongside technology choices. Projects reaching financial close will be those supported by robust FEED studies, defensible dispatch simulations and connection agreements that permit the full operating profile envisioned by developers.
