Romania’s power market has shown extreme intraday price movements, with abundant solar generation pushing prices towards zero during midday before a sharp evening recovery. The pattern highlights how Romania’s price curve can move away from a single daily reference point. OPCOM pricing has reflected this shift within the same delivery day.
Before noon, OPCOM prices fell below €20/MWh. They reached zero across multiple fifteen-minute intervals and stayed close to zero for several hours. After 17:00, prices rose quickly, exceeding €150/MWh during the evening and reaching €310/MWh shortly before 21:00.
Solar concentration and operational constraints in Romania’s generation mix
Romania can face renewable oversupply and power adequacy challenges on the same delivery day. Solar capacity has expanded rapidly through both utility-scale projects and a growing prosumer fleet. This output is concentrated in daylight hours and has limited flexibility to adjust to changing market conditions.
Nuclear availability is also a factor in balancing conditions. One of Cernavodă’s two 680 MW reactors is unavailable, while the remaining unit continues to face cooling-water risks. Hydropower output has been weakened by record-low Danube flows and poor reservoir conditions.
As solar generation declines in the evening, Romania may need to rely on gas, coal, imports, storage or demand-side flexibility to cover the shortfall. The scale of the shift is visible in demand and available supply expectations for tight periods. Domestic demand was recently expected to reach around 7,300 MW, compared with available internal generation of approximately 4,000–4,300 MW.
Zero-price periods and the role of battery storage
The same-day move from near-zero pricing to scarcity levels illustrates how quickly market conditions can change. It also creates an opportunity for battery energy storage based on intraday spreads. A two-hour battery charging window during the zero-price period and discharging around the evening peak could theoretically capture a spread approaching €300/MWh.
Theoretical revenues would be lower after accounting for round-trip efficiency losses, degradation, grid charges, imbalance exposure and market-access costs. Even so, the underlying arbitrage mechanism remains relevant under these price patterns.
Planned storage additions and implications for revenue models
Authorities are preparing commercial approvals for 324 MW of new capacity. The package includes 176 MW of storage alongside 148 MW of photovoltaic and wind projects. A further 990 MW is reportedly moving through documentation and validation.
In the near term, additional storage is expected to provide flexibility for the Romanian power system. Over time, added batteries may compete for the same low-price charging periods and evening discharge opportunities. Projects relying exclusively on day-ahead arbitrage may therefore face revenue compression, increasing attention on balancing services, ancillary markets and congestion-related revenues.
Batteries’ market role is therefore linked to how frequently low-price periods occur and how quickly they can be monetised through discharge during higher-price hours.
