Romania’s second contracts-for-difference auction has confirmed that solar power is becoming the dominant growth engine in Southeast Europe. The round awarded 1,488 MW across 26 photovoltaic projects, helping move the Romanian market from fragmented merchant development toward large assets supported by predictable long-term revenues.
The flagship name is Dama Solar, Rezolv Energy’s planned development in western Romania. At approximately 1.04 GW in total planned capacity, it is on a scale rarely attempted in the region. Reported auction results show that 211 MW secured support at a strike price of €65.17/MWh. The figure matters because it gives investors and lenders a transparent reference for the revenue level at which a major Romanian solar project can attract capital.
Romania’s auction design protects projects from low wholesale prices while requiring them to return excess revenue when reference prices rise above the contracted level. This reduces exposure to volatile spot markets and can lower financing costs. The second round’s solar ceiling of €73/MWh also imposed price discipline, encouraging competition rather than offering an open-ended subsidy.
The results show the different speeds at which solar and wind are advancing. More than 2.75 GW of combined renewable capacity was awarded, but the available wind quota was not fully used. Solar projects generally have shorter construction schedules, simpler supply chains and fewer siting constraints. In a market seeking rapid capacity additions, those advantages are decisive.
Yet Romania’s solar success is creating its next market problem. Across SEE, strong photovoltaic output is increasingly pushing daytime electricity prices close to zero, while prices rise sharply after sunset. On 19 July 2026, reported Romanian day-ahead prices fell to €0.02/MWh during the solar window and later climbed to €154.13/MWh. Bulgaria and Greece experienced almost identical swings. The figures provide a clear warning: additional solar capacity does not automatically translate into consistently cheap electricity.
For solar owners, this pattern reduces the capture price—the average value actually earned when a plant generates—relative to the market’s overall average price. A CfD can protect awarded capacity, but merchant projects and projects whose contracts eventually expire face growing exposure to price cannibalisation. Curtailment risk also rises when transmission capacity, flexible demand and storage fail to keep pace.
The next stage of Romania’s solar market will therefore be about the quality of integration rather than the quantity of modules installed. Batteries can move energy into evening hours; industrial consumers can shift production toward low-price periods; stronger interconnectors can export surpluses; and hybrid solar-wind portfolios can produce a more balanced profile. Developers able to combine these elements will have an advantage over owners of standalone, inflexible generation.
The regional implications are substantial. Romania’s relatively large and liquid market can become a source of competitively priced renewable electricity for neighbouring countries. Cross-border corporate power-purchase agreements could extend further into solar. At the same time, very large developments such as Dama Solar’s approximately 1.04 GW pipeline will increase pressure on the transmission system and may affect price formation from Hungary and Bulgaria to Serbia and Moldova.
Romania’s auction has proved that solar projects can be procured at scale and at competitive prices. The next phase will be determined by the ability of developers and the transmission system to preserve the value of those megawatt-hours as 1.5 GW-scale auction rounds add increasingly concentrated midday production to the market.
