The solar energy landscape in South-East Europe (SEE) is undergoing significant transformation as utility-scale photovoltaic (PV) installations reach levels that notably impact intraday electricity pricing. Countries like Hungary, Romania, and Greece have seen their solar capacities grow substantially, shifting from mere expansion to a phase of structural integration. Despite this growth, recent performance metrics from January to February 2026 reveal that the increasing solar penetration is not sufficient to displace gas as the marginal price setter during peak demand periods.
In Hungary, the solar sector has emerged as one of the most intensive in the region. The midday generation from solar facilities often compresses spot prices, leading to narrower price spreads between base and peak demand during daylight hours. However, the winter months pose a challenge; lower irradiance limits energy production at times when evening demand peaks, exacerbating ramp risk as gas-fired plants must compensate for this gap.
Romania’s solar market is transitioning towards more sophisticated financial models. The previous reliance on merchant exposure is being replaced by hybrid revenue frameworks that incorporate contract-for-difference mechanisms alongside corporate power purchase agreements. This evolution reflects a growing maturity in capital management among developers, particularly as market forecasts increasingly factor in uncertainties linked to gas prices.
Greece faces perhaps the most complex integration obstacles due to congestion and curtailment issues stemming from inadequate transmission infrastructure. The rapid deployment of PV systems has outpaced enhancements to grid capabilities, particularly in export-constrained areas. Consequently, curtailment risks are becoming a relevant pricing factor rather than occasional operational challenges. For many projects, integrating battery storage has shifted from being a strategic option to a necessity for ensuring financial viability.
Three key observations emerge regarding the systemic effects of solar energy on market dynamics as of early 2026. First, midday solar production reshapes intraday price curves, resulting in reduced revenue for merchant plants and increased volatility during trading hours from noon to 8 PM. Second, the sensitivity of ramping increases as daytime generation diminishes quickly during winter months, necessitating aggressive responses from gas-fired units and reinforcing gas’s role in setting marginal prices. Third, saturation within systems raises the likelihood of curtailment; without significant upgrades to grid infrastructure or increased storage capacity, additional PV installations yield diminishing returns on price suppression.
For solar energy to effectively alter the regional price ceiling in SEE, substantial structural changes are required—specifically large-scale battery deployments, enhanced cross-border transmission capabilities, or improved demand-side flexibility. In the absence of these developments, solar will primarily serve as a daytime price influencer rather than fundamentally changing pricing ceilings.
Looking forward, hybridization appears crucial for optimizing solar output. Projects currently under development are increasingly integrating PV arrays with short-duration battery storage systems capable of 2–4 hours of discharge. This configuration enables developers to shift generation into peak demand periods, enhancing revenue capture while mitigating curtailment risks. However, existing storage capabilities across SEE remain insufficient to significantly diminish gas-driven peak pricing.
The trajectory of solar energy in South-East Europe encapsulates a paradox: while capacity continues to expand and capital structures evolve toward greater sophistication and awareness of curtailment risks rises, gas remains dominant in determining marginal pricing during periods of high stress.
