The renewable story in Southeast Europe during Week 22 was not a straightforward story of more green generation. Total variable renewable output fell 10.1%, from 3.74 TWh to 3.36 TWh, because wind generation dropped 30.0%, equal to 532 GWh. Solar generation moved in the opposite direction, rising 7.8%, or 153 GWh. The result was a cleaner but more uneven production profile: stronger daytime solar support, weaker wind contribution and greater exposure to evening scarcity. As reported by Electricity.trade, the week showed that SEE power prices are increasingly shaped not only by how much renewable energy is produced, but by which technology produces it and when.
This distinction is becoming central to market analysis. Wind and solar have very different commercial effects. Solar output is concentrated in daylight hours, often compressing midday prices when demand is moderate and photovoltaic production peaks. Wind can be more valuable when it generates overnight, in the evening or during broader scarcity periods. When wind falls sharply, as it did in Italy, Türkiye and Romania during Week 22, systems may need more gas, coal, hydro or imports to cover non-solar hours.
Italy was the clearest example. Wind generation fell heavily, contributing to a 32.6% increase in thermal output and a 25.3% increase in gas-fired generation. Italy’s weekly price rose to €123.58/MWh, even as its hydro generation improved and imports exceeded 1.1 TWh. Solar alone could not offset the commercial impact of weak wind during higher-value hours.
Bulgaria showed the other side of the story. Strong solar output helped reduce prices by 11.3% and lifted net exports from 6 GWh to 61 GWh. That was positive for system balance, but it also points toward capture-price pressure. As more solar enters the market, midday prices can soften more often, reducing merchant revenues unless projects are paired with storage, flexible offtake or hedged contracts.
For traders, the wind-solar split creates more complex hourly strategies. A weekly renewable number is no longer enough. The key questions are whether solar will depress noon prices, whether wind will support evening ramp periods, whether hydro can bridge the gap, and whether gas will become marginal after sunset. The value of forecasting therefore rises sharply.
For developers and lenders, Week 22 reinforced the need to model wind and solar separately. A solar project and a wind project do not carry the same price risk, curtailment profile or system value. In SEE, wind may retain stronger value during non-solar hours, while solar increasingly requires storage and flexible commercial structuring.
The regional data show a market in transition. Solar is growing, but weak wind still leaves evening prices exposed. The future value of renewables in SEE will depend less on headline megawatt-hours and more on hourly delivery, grid location and the ability to match production with scarcity.
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