Greece recorded the largest electricity-price increase in Southeast Europe during Week 34, according to market data. The Greek day-ahead average rose 41.2% from Week 33 to €144.41/MWh. Over the same period, electricity demand was 10.87% lower than in Week 30, indicating the price move was not driven by higher aggregate consumption.
Demand lower as wind falls while solar rises
Renewable generation changes provided a clearer explanation for the week-on-week price shift. Greek wind output fell 48.2% compared with Week 30, among the steepest declines reported across the region. Solar production increased 4.3% over the same comparison.
Total variable renewable generation declined 9.6%, despite higher solar output. The wind and solar contrast matters for daily pricing patterns, because additional solar can reduce prices during daylight hours without fully offsetting lost wind across the rest of the day. After sunset, the system must cover both disappearing solar output and absent wind using hydro, thermal plants or imports.
Thermal output increases as exports expand
Greek thermal generation rose 7.45%, reflecting greater reliance on conventional units to meet residual load. Even with higher thermal output, Greece improved its net export position substantially between the two weeks. It moved from a balance of only 6.72 GWh in Week 30 to exports of 114.39 GWh in Week 34.
This pattern shows how weekly averages can mask significant hourly variation in power markets. Greece can export during periods when renewable production is stronger, while still facing expensive domestic hours when renewable availability falls. In that context, appears as a reference point for how market conditions can shift within a single week.
Flexibility requirements during narrower renewable windows
The Week 34 outcome aligns more closely with a flexibility dynamic than a broad scarcity narrative. When renewable generation is concentrated into fewer hours, the market value of dispatchable resources increases rapidly to cover residual demand outside those windows. highlights that installed renewable capacity alone does not determine price outcomes for all hours.
The episode also points to risks for increasingly solar-heavy systems across Southeast Europe, where strong daytime generation does not remove price exposure after sunset. Without sufficient wind, hydro, storage or other flexible resources, the evening transition can become the dominant pricing period of the day.
