Variable renewable generation rose 30.1% to 3,597.48 GWh across Southeast Europe in Week 42, yet wholesale electricity prices increased in every market covered. Serbia recorded a 28.53% weekly price rise, followed by Bulgaria at 12.60%, Croatia at 11%, Romania at 9.72%, Hungary at 8.99% and Greece at 6.70%. The figures are provided courtesy of Virtu.Energy’s market data.
Regional wind generation jumped 86.6% to 2,133.35 GWh, driving the increase in wind and solar electricity output. Solar production, by contrast, fell 9.7% to 1,464.13 GWh. Higher renewable output across the region did not, on its own, bring down wholesale prices.
National output and hourly prices
Türkiye accounted for a large share of the regional increase in renewable generation, while Italy also added substantial production. Romania and Greece posted strong wind gains, but Bulgaria’s combined wind and solar output dropped 21.5%. Hungary also recorded weaker variable renewable generation, underscoring the differences behind the regional total.
Electricity prices depend on conditions during individual hours when the marginal source of supply sets the price, not just on average weekly renewable production. A system may have plentiful wind power overnight but still face costly evening peaks if renewable output falls as demand strengthens. Renewable generation also varies by location, limiting the effect of a regional increase on any one market.
Transmission constraints can preserve large wholesale price differences between bidding zones. Lower-cost renewable electricity may be available in a surplus zone but unable to reach a deficit market. In Week 42, Greece combined stronger renewable generation with higher electricity exports and comparatively low prices. Serbia increased wind and solar output but moved substantially further into net imports as demand rose and hydropower generation declined.
Flexibility and project revenues
The investment debate in Southeast Europe is consequently extending beyond installed renewable capacity to storage, transmission, demand response and portfolio management. Battery energy storage systems can retain surplus wind and solar power during lower-priced periods and discharge it during evening peaks. Cross-border interconnectors can transfer renewable surpluses between markets, while flexible hydro and thermal plants can offset fluctuations in output.
Industrial demand response can ease pressure on the system during expensive hours. For renewable developers, project revenue will increasingly depend on the hourly generation profile rather than annual MWh production alone. Two solar plants with identical annual output can have different economics if one faces midday price compression in a congested market and the other has access to storage or greater cross-border capacity.
The distinction also matters for corporate power purchase agreements (PPAs). Buyers seeking predictable energy costs need to distinguish between buying annual renewable volumes and securing electricity in the hours when their facilities consume it. Week 42’s higher renewable output alongside rising prices shows the importance of moving, storing and shifting generation to the hours and locations where it has the highest value.
