On March 26, 2026, day-ahead electricity prices across Southeast Europe and Hungary experienced substantial increases, highlighting a stark contrast between the tightly balanced core markets and the softer pricing observed in the western Balkans. This divergence is attributed to declining wind output and reduced thermal generation that has tightened supply conditions across the region.
In Hungary, the HUPX day-ahead price soared to €133.6/MWh, reflecting a daily increase of €26. Neighboring markets followed suit, with Croatia’s CROPEX climbing to €130.8/MWh (+€25) and Slovenia’s BSP rising to €122.4/MWh (+€14.8). Albania recorded the most significant jump, with ALPEX reaching €121.6/MWh, up by €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 further declined to €65.6/MWh, resulting in a discount of nearly €70/MWh compared to Hungarian prices.
This pricing divergence reflects tightening fundamentals in Central Europe, characterized by increased demand and diminished dispatchable generation capacity that has driven marginal prices higher. Regional consumption rose to 34.5 GW, an increase of 1.8 GW day on day, while total generation fell by over 1.6 GW.
A significant decline in thermal output was noted, with gas-fired generation decreasing by 763 MW, coal output down 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 particularly evident in intraday price movements; hourly prices in Hungary peaked above €270/MWh, while minimum prices during solar hours remained close to zero, illustrating pronounced “duck curve” dynamics across the region.
Cross-border electricity flows maintained relative stability, with net imports into Southeast Europe and Hungary around -457 MW. Inflows from Austria and Slovakia consistently exceeded 1.9 GW. However, limited additional import capacity and congestion on key interconnectors hampered further balancing efforts, reinforcing upward pressure on core market prices.
This spot price rally occurred despite a lack of supportive trends in fuel markets; Austrian CEGH gas prices declined to approximately €53.5/MWh, while coal benchmarks softened and carbon prices continued their gradual rise. This indicates that current price formations are increasingly influenced by system flexibility rather than input costs.
<pIn the western Balkans, lower electricity prices suggest relatively stable domestic generation sources, particularly from coal and hydroelectric power, along with diminished exposure to regional pricing signals. Nonetheless, the widening gap with Central European hubs highlights ongoing structural fragmentation and limited integration capacity within these markets.
The latest trading session underscores a broader evolution in Southeast European electricity markets where short-term price fluctuations are becoming increasingly sensitive to renewable energy variability and the availability of flexible generation resources. As wind output declines and thermal capacity proves less responsive, balancing constraints are likely to become more frequent during peak demand periods.
<pLooking forward, market participants anticipate continued volatility in pricing dynamics, particularly if wind generation remains low while demand persists at elevated levels. The growing disparities between core and peripheral markets may sustain cross-border trading opportunities; however, physical transmission limits are expected to remain a significant constraint moving ahead.
