Romania has accumulated 143 battery-storage projects with combined power capacity of 9,147 MW in advanced stages of development, according to information submitted to the energy regulator by transmission and distribution operators.
Of that portfolio, 36 projects totalling 2,050 MW are scheduled to enter operation by the end of 2026. Romania had installed nearly 600 MW by the end of 2025, meaning the market could more than triple within a single year if the announced projects reach commercial operation on schedule.
The expansion is being driven by the widening difference between solar-rich daytime prices and the evening peak. Storage developers can charge when renewable output depresses the market and discharge when demand remains high but solar generation has disappeared. Batteries can also earn revenue from frequency response, balancing and reserve products.
An ENTSO-E assessment estimates potential average daily battery revenue in Romania at approximately €792 per MW of installed capacity, ranking the country fourth in Europe behind Hungary, Bulgaria and Greece. Annualised without adjustment, that would equal almost €289,000 per MW-year.
That figure reflects current scarcity and should not be treated as a stable long-term revenue forecast. It is a market signal produced by limited interconnection, renewable volatility and insufficient flexibility. Revenue per installed megawatt is likely to decline as storage deployment increases and participants compete for the same balancing and arbitrage opportunities.
Duration is also missing from headline pipeline statistics. A 9.1 GW portfolio of one-hour batteries would represent a very different investment and system resource from the same power capacity configured for two or four hours. Energy capacity, cycling strategy and connection rights will determine how much of the pipeline can genuinely shift solar output into the evening.
Romania’s wider renewable queue intensifies the case for storage. Approximately 1,530 renewable projects, representing more than 91 GW of approved export capacity, are seeking network connections. Operators expect 647 projects totalling around 30.4 GW to commission between 2026 and 2035.
The numbers also expose a credibility gap. Romania’s electricity system cannot absorb every announced renewable and storage project without major transmission reinforcement, revised connection rules and a disciplined approach to speculative capacity reservations. Some projects will be delayed, resized, sold or cancelled.
Co-located storage may have an advantage over standalone projects where it shares infrastructure with solar or wind generation and uses otherwise underutilised connection capacity. Yet the commercial model must specify whether batteries can charge from the grid, whether charging counts against import capacity and how priority is allocated between generation and storage.
Financing will become increasingly selective. Early projects may capture strong balancing revenue, but later developments will need diversified income, conservative spread forecasts and robust degradation modelling. Lenders are likely to distinguish between projects with secured land, construction-ready permits and binding grid agreements and those holding little more than preliminary development rights.
Romania’s storage market has moved beyond experimentation. The next phase will determine which portion of the 9,147 MW pipeline represents deliverable infrastructure and which portion reflects competition for scarce grid capacity.
