Variable renewable generation in Southeast Europe declined in Week 22, falling 10.1% from 3.74 TWh to 3.36 TWh. The drop was linked to a 30.0% fall in wind output, equivalent to 532 GWh. Solar generation increased by 7.8%, adding 153 GWh, moving in the opposite direction to wind.
The weekly mix left production cleaner but more uneven across the day. Stronger daytime solar contribution coincided with weaker wind support outside solar hours. That pattern increased exposure to evening scarcity conditions, according to Electricity.trade.
How wind and solar timing affects power prices
The week highlighted that Southeast Europe power prices are influenced not only by renewable volumes, but also by which technology generates and when it produces. Solar output is concentrated in daylight hours, which can affect midday pricing when demand is moderate and photovoltaic generation peaks. Wind generation can be more relevant during overnight and evening periods, including broader scarcity intervals.
When wind output falls sharply, systems may need additional supply from conventional generation or cross-border flows to cover non-solar hours. During Week 22, wind declines occurred in Italy, Türkiye, and Romania. The resulting shift in generation requirements extended into periods when solar contribution is limited.
Italy sees higher thermal and gas output as wind drops
Italy provided the clearest example of the impact of weaker wind on system dispatch. Wind generation fell heavily, contributing to a 32.6% increase in thermal output. Gas-fired generation rose by 25.3%.
Italy’s weekly price increased to €123.58/MWh. The price rise occurred alongside improved hydro generation and imports exceeding 1.1 TWh. Solar output alone was not sufficient to offset the commercial effect of weak wind during higher-value hours.
Bulgaria records lower prices with stronger solar exports
Bulgaria showed a different outcome as solar output strengthened. Stronger solar helped reduce prices by 11.3%. Net exports increased from 6 GWh to 61 GWh.
The shift supported system balance while also indicating potential capture-price pressure as more solar enters the market. With additional photovoltaic generation, midday prices can soften more frequently, which may affect merchant revenues unless projects are paired with storage or structured with flexible offtake or hedged contracts.
Market implications for trading and project modelling
The wind-solar split changes how participants approach hourly pricing rather than relying on a single weekly renewable figure. For traders, the key operational questions include whether solar depresses noon prices and whether wind supports evening ramp periods. Other considerations include whether hydro can bridge gaps and whether gas becomes marginal after sunset.
The forecasting requirement therefore increases as hourly patterns diverge between technologies. For developers and lenders, Week 22 reinforced the need to model wind and solar separately because they do not carry the same price risk or curtailment profile. In Southeast Europe, wind may retain stronger value during non-solar hours, while solar increasingly depends on storage and flexible commercial structuring.
The regional data point to a market transition where solar growth coexists with evening price exposure tied to weak wind performance. Future renewable value in Southeast Europe is expected to depend less on headline megawatt-hours and more on hourly delivery, grid location, and matching production with scarcity conditions.
