Week 24 saw a general decline in day-ahead electricity prices across most markets in South East Europe, alongside higher coal and lignite generation. The change coincided with a rise in renewable output and a sharp fall in hydropower production.
Hydropower declines and regional thermal generation rises
Regional hydro production decreased by 300.2 GWh, or 7.5%, to 3.70 TWh. Türkiye recorded the largest reduction at 229 GWh, followed by Bulgaria with 42.9 GWh, Greece with 17.3%, Serbia with 4.2%, Romania with 2.4%, and Italy with 2.2%. The drop removed flexible, low-marginal-cost generation as summer demand began to increase.
Thermal generation increased by 362.6 GWh, or 8.7%, reaching 4.52 TWh. Coal and lignite accounted for the full increase, rising by 420.6 GWh, or 24.4%, to 2.14 TWh. Gas-fired generation fell by 58.0 GWh, or 2.4%, to 2.38 TWh.
Coal-led dispatch changes across Türkiye, Italy and Serbia
Türkiye led the coal expansion with an additional 260.6 GWh. Italy added 81.2 GWh, while Serbia increased by 66.0 GWh. Bulgaria and Romania also recorded increases in coal and lignite output.
The resulting dispatch mix became more coal-intensive even as stronger wind and solar output helped keep wholesale prices under pressure. This combination affected how generation was scheduled during the period of reduced hydro availability.
Implications for carbon exposure reporting among industrial buyers
For industrial power buyers focused on carbon exposure and emissions reporting, the relationship between price and generation mix is relevant. In Week 24, cheaper power in several markets coincided with higher coal and lignite usage tied to lower hydropower availability.
Renewables continued to influence daytime pricing patterns while hydropower variability determined how much thermal generation was needed during peak and evening hours during the summer period.
