Electricity markets across Central and South-East Europe traded significantly lower on 11 March 2026, with day-ahead prices falling across most regional exchanges as milder weather conditions reduced demand while renewable generation increased supply.
The Hungarian HUPX day-ahead price settled at €111.01/MWh, representing a sharp €26.3/MWh decline day-on-day. Prices in neighbouring markets moved in the same direction. Both Romania’s OPCOM and Bulgaria’s IBEX cleared around €93.83/MWh, roughly €16.1/MWh lower compared with the previous session.
Demand remained relatively stable but below winter peak levels. Forecast system consumption across the region reached roughly 33,280 MW, increasing by 221 MW day-on-day, but still reflecting moderate seasonal demand conditions.
Renewable production contributed to the softer market balance. Regional solar generation reached approximately 4,376 MW, while wind production stood near 889 MW. Although wind output was below peak seasonal levels, the combined renewable generation significantly reduced the need for marginal thermal generation during daylight hours.
Commodity benchmarks also reinforced the bearish tone in power markets. The CEGH gas benchmark traded at €48.62/MWh, down €11.1/MWh, while EU carbon allowances (EUA) traded near €72.91/t. Lower gas prices improved the competitiveness of gas-fired plants relative to coal while simultaneously reducing the marginal clearing price in several regional markets.
Forward power contracts reflected expectations of continued price softness in the coming weeks. Hungarian futures were quoted near €105/MWh for week 12, while April 2026 base contracts traded around €96/MWh, indicating that traders anticipate relatively balanced fundamentals through early spring.
Cross-border flows: Romania and Slovenia anchor regional supply
Cross-border electricity flows remain one of the dominant structural features of SEE power markets. Interconnected systems allow excess generation in several countries to shape price formation across neighbouring markets.
Romania continues to play a critical role as a regional balancing hub. Average generation on 11 March reached approximately 4,152 MW, slightly exceeding domestic consumption of 4,138 MW. This enabled Romania to maintain export flows across several interconnections.
Romanian exports toward Bulgaria reached approximately 1,300 MW, while flows toward Serbia approached 700 MW, highlighting the importance of Romanian generation in balancing the Western Balkan system.
The Romanian generation mix remained heavily dominated by coal and hydro production. Coal-fired plants contributed around 2,327 MW, while hydropower generation reached roughly 1,168 MW.
Further west, Slovenia maintained a relatively balanced system supported by nuclear baseload generation. Total generation averaged 1,587 MW, compared with domestic consumption of 1,619 MW. Slovenia’s system remained anchored by 702 MW of nuclear output from the Krško plant, complemented by 377 MW of hydropower generation.
These cross-border dynamics increasingly determine regional price convergence. When interconnections remain unconstrained, surplus electricity from Romania or Slovenia quickly flows into neighbouring systems, compressing price spreads between markets such as Hungary, Serbia, Croatia and Bulgaria.
However, temporary transmission congestion can quickly fragment the market, creating trading opportunities for participants able to arbitrage between hubs.
Renewable volatility: Short-term supply swings drive trading opportunities
Renewable generation remains the most important source of short-term volatility in SEE electricity markets. Rapid fluctuations in wind and solar output can significantly alter supply-demand balances and influence day-ahead price formation.
Romania illustrates the scale of this volatility. Wind generation reached 614 MW during the observed trading period, compared with only 54 MW earlier in the week, reflecting rapidly changing weather conditions. Solar production in the country reached approximately 739 MW, contributing additional supply during daytime trading hours.
Hydropower remains another critical balancing source in the region. Romanian hydro generation averaged 1,168 MW, while Albania’s electricity system continued to rely heavily on hydropower, with roughly 55% of total generation coming from hydro assets.
Greece provides another example of the evolving generation mix in SEE markets. Wind generation accounted for approximately 22% of total output, while gas-fired power plants contributed around 25%, demonstrating the increasing interaction between renewable variability and flexible thermal generation.
For trading desks, the growing share of intermittent renewable generation significantly increases the importance of short-term forecasting tools. Wind output across the region has been observed moving from 600 MW to more than 2,400 MW within a few days, producing rapid shifts in market fundamentals.
As renewable capacity continues expanding across the Balkans, these fluctuations are expected to become more pronounced. Without major grid reinforcement and additional storage capacity, the SEE electricity market will likely experience increasing price volatility, reinforcing the strategic importance of intraday trading, cross-border arbitrage and flexible generation assets.
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