On March 26, 2026, day-ahead electricity prices across Southeast Europe and Hungary experienced significant increases, driven by tightening supply conditions as wind output declined and thermal generation fell. This divergence has resulted in a stark contrast between the core markets, where prices surged, and the western Balkans, where pricing remained soft.
Hungary’s HUPX market saw its day-ahead price rise to €133.6/MWh, marking a substantial increase of €26 from the previous day. Neighboring markets also reported similar upward trends; Croatia’s CROPEX climbed to €130.8/MWh (+€25), Slovenia’s BSP reached €122.4/MWh (+€14.8), and Albania recorded the most significant jump with ALPEX soaring to €121.6/MWh, up €50.
Conversely, eastern and southern markets faced downward pressure. Romania’s OPCOM fell to €87.6/MWh (-€9.3), Bulgaria’s IBEX decreased to €84.8/MWh (-€2.5), and Serbia’s SEEPEX dropped further to €65.6/MWh, widening its discount to Hungarian prices by nearly €70/MWh.
This pricing divergence highlights the tightening fundamentals in Central Europe, where increased demand and reduced dispatchable generation have pushed marginal prices higher. Regional consumption rose to 34.5 GW, an increase of 1.8 GW day-on-day, while total generation decreased by over 1.6 GW.
A notable decline in thermal output was observed, with gas-fired generation down by 763 MW, coal output reduced by 548 MW, and wind production dropping by 410 MW. Although solar generation increased by more than 1 GW, it was insufficient to compensate for the loss of flexible capacity during peak evening hours.
The tightening supply-demand balance was evident in intraday price behavior, with hourly prices in Hungary peaking above €270/MWh. Minimum prices during solar hours remained close to zero, indicating pronounced “duck curve” dynamics across the region.
Cross-border electricity flows remained relatively stable, with net imports into Southeast Europe and Hungary at approximately -457 MW. Inflows from Austria and Slovakia exceeded 1.9 GW, but limited import capacity and congestion on key interconnectors hindered further balancing efforts, thereby reinforcing upward price pressure in core markets.
Despite the surge in spot prices, fuel markets did not provide significant support for this increase. Austrian CEGH gas prices edged lower to around €53.5/MWh, while coal benchmarks softened and carbon prices gradually trended upward. This indicates that current price formation is increasingly influenced by system flexibility rather than input costs.
<pIn the western Balkans, lower electricity prices suggest a more stable domestic generation mix, primarily from coal and hydro resources, along with reduced exposure to regional pricing signals. However, the widening spread between these markets and Central European hubs underscores ongoing structural fragmentation and limited integration capacity.
Market analysts noted that recent trading sessions reflect a broader shift within Southeast European electricity markets, where short-term price formation is becoming increasingly sensitive to renewable energy variability and the availability of flexible generation resources. With declining wind output and less responsive thermal capacity, balancing constraints are occurring more frequently during peak demand periods.
Looking forward, traders anticipate continued volatility in electricity pricing dynamics. Elevated peak prices are expected to persist if wind generation remains low while demand stays robust. The growing disparities between core and peripheral markets are likely to sustain cross-border trading opportunities; however, physical transmission limitations will continue to pose significant challenges.
