Solar power supplied 25% of total electricity generation in the European Union in June 2026, making it the bloc’s largest electricity source. The change meant solar overtook nuclear for only the third month on record. Photovoltaic installations produced approximately 52 TWh during the month.
Nuclear accounted for 21% of the EU generation mix, followed by natural gas at 15%, wind at 14%, hydropower at 12%, and coal at 8%. The figures reflect years of capacity additions rather than a single weather-driven outcome. Installed solar capacity across the EU expanded by more than 20% annually between 2021 and 2025.
Solar output shares in Germany, Spain and Poland
During June, Germany recorded one of the highest solar contributions, with photovoltaic plants supplying 36% of national electricity demand. Spain reached 34%, while Poland generated 24% of its electricity from solar. Coal remained important in Poland’s power system alongside the higher solar share.
The scale of photovoltaic generation increased during spring and summer daylight hours as installed capacity grew. This pattern is linked to rapid additions over multiple years. As a result, solar output became a more prominent driver of daily generation profiles during those periods.
Impact on wholesale prices and dispatch patterns
The higher photovoltaic output affected wholesale price formation by compressing midday prices more frequently. That development reduced thermal-unit running hours and shifted merchant value toward the evening ramp. Electricity markets increasingly place weight on dispatch profile, grid location, and the ability to deliver power after sunset.
Markets are no longer assigning the highest value solely based on annual renewable output. Instead, delivery timing relative to demand and system constraints has become more important for pricing outcomes.
Southeast Europe price swings during solar-intensive periods
The change is already visible in Southeast Europe where solar-heavy conditions can alter price levels quickly. Solar-intensive periods have moved some markets from deeply discounted midday prices to scarcity pricing within several hours. On 15 July, Greek day-ahead electricity fell to €30.50/MWh during the solar-intensive period before rising to almost €197/MWh in the evening.
On the same date, Hungary moved from €90.10/MWh to €275.80/MWh. Slovenia reached more than €372/MWh.
Storage, flexibility needs and curtailment risks for photovoltaics
A larger solar share strengthens the commercial case for battery storage, flexible hydropower, demand response, and improved cross-border transmission. It also increases curtailment and capture-price risks for photovoltaic projects developed without storage or a clearly structured industrial offtake profile.
The EU’s 25% solar market share indicates that renewable deployment is moving into a phase where grid investment, storage, forecasting, and flexible consumption need to keep pace with generation growth. During daylight hours, electricity becomes more abundant while dependable delivery during constrained periods becomes more valuable for market outcomes.
