Southeast Europe moved into a visibly tighter summer electricity regime in the final week of June, with the regional market no longer shaped only by normal seasonal volatility but by a clear combination of heat-driven demand, heavier thermal dispatch and sharper price formation in the evening hours. During Week 26, 22–28 June 2026, total electricity consumption across the monitored SEE markets rose by 12.7% week on week to 18.41 TWh, creating one of the clearest early-summer stress signals of the year.
The price reaction was broad. Most SEE markets moved above €100/MWh on weekly average, while the upper end of the region was led by Hungary at €149.92/MWh, Romania at €148.78/MWh, Italy at €144.67/MWh and Croatia at €139.09/MWh. Serbia also moved firmly into triple-digit territory, reaching €110.77/MWh, while Bulgaria averaged €104.24/MWh. Greece remained below the main high-price cluster at €99.98/MWh, but even there the market recorded a meaningful weekly increase. Türkiye remained structurally separate from the rest of the region, averaging only €27.39/MWh, despite a sharp percentage rise.
The main driver was not fuel alone, but the speed at which demand increased. Italy added more than 1.2 TWh of weekly demand and reached 6.49 TWh, while Croatia, Hungary, Serbia, Romania and Greece all recorded strong gains. Cooling load has become the dominant summer variable, and Week 26 showed how quickly it can turn regional systems from balanced to tight. This is particularly important in SEE, where hydro, lignite, gas, imports and renewable availability interact differently across each national system.
Supply did respond, but not cleanly enough to prevent price pressure. Variable renewable generation increased by 11.7% to 4.27 TWh, helped by stronger wind output, yet solar was broadly flat and renewable gains were uneven across countries. Hydro slipped by 2.8% to 3.51 TWh, weakening one of the region’s most important balancing sources. Thermal generation had to fill the gap, rising 24.7% to 6.52 TWh, with gas-fired production up 25.5% and coal and lignite output up 23.6%.
The commercial signal from the week is direct: SEE is entering a summer market in which average prices matter less than peak-hour exposure. Industrial buyers, traders and renewable generators now face a system where the most valuable hours are created by the evening ramp, not by baseload scarcity alone. The late-June data points toward a July market shaped by cooling demand, thermal marginality, hydro availability and the ability of countries to secure flexibility across borders.
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