Electricity prices across much of Southeast Europe moved above €200/MWh for Oct. 5 delivery as weekday demand rose and wind generation fell. In parallel, Greece recorded hours with negative prices during periods of high solar output.
Day-ahead price jumps in Hungary, Romania and neighbouring markets
On HUPX, Hungary’s day-ahead average increased by €71.90/MWh to €232.76/MWh. Romania’s day-ahead average climbed by €67.50/MWh to €228.48/MWh. Croatia reached €219.83/MWh, while Slovenia settled at €217.71/MWh and Bulgaria at €203.78/MWh.
Albania recorded the largest rise in the region, increasing by almost €120/MWh to €277.08/MWh. The changes coincided with lower forecast wind output and higher overall demand in the monitored area.
Demand, wind outlook and net import flows into the monitored region
Regional electricity demand increased by about 10.6%, reaching 28.7 GW. Forecast wind output declined by around 886 MW. Net imports into the monitored SEE region rose to roughly 1.64 GW.
Serbia remained comparatively low at €169.68/MWh, leaving SEEPEX more than €60/MWh below Hungary and Romania. The price gap reflected constraints on cross-border capacity under the prevailing conditions.
Greece’s negative-price hours amid high solar generation
Greece showed a different pattern from the rest of the region, with a daily average around €148–150/MWh. Solar generation pushed prices below zero for almost eight hours, before prices rebounded sharply after sunset.
The divergence highlighted how market outcomes differed across countries during the same delivery period. Some systems faced evening scarcity and import dependence, while others dealt with midday renewable oversupply.
Flexibility value tied to timing and location of renewable output
The shifting balance between scarcity periods and renewable oversupply supported a commercial premium for assets that can respond to timing differences. Batteries, pumped hydro, flexible demand and transmission capacity capable of moving electricity across both time and geography were referenced as beneficiaries of that pattern.
The regional system was producing more renewable power, but the value depended on when and where each megawatt was available.
