The day-ahead electricity markets across Southeast Europe (SEE) and Hungary on February 25, 2026, reveal a fragmented pricing structure, highlighting the region’s incomplete convergence towards a unified power market. Prices varied significantly, with Hungary’s HUPX reporting a base price of 107.7 EUR/MWh, while ALPEX in Albania cleared at just 45.5 EUR/MWh. Other notable prices included Slovenia’s BSP at 100.4 EUR/MWh, Croatia’s CROPEX at 94.1 EUR/MWh, Romania’s OPCOM at 59.0 EUR/MWh, Greece’s HENEX at 54.5 EUR/MWh, Serbia’s SEEPEX at 53.6 EUR/MWh, and Montenegro’s BELEN also at 54.5 EUR/MWh. The over 60 EUR/MWh price gap between Hungary and Albania underscores the ongoing challenges in achieving price uniformity across the region, influenced by factors such as generation mix, transmission limitations, and liquidity levels.
Hungary’s pricing above the 100 EUR/MWh mark positions it within the Central European pricing framework, where gas-fired generation and cross-border electricity flows are increasingly pivotal in determining market clearing prices. Slovenia’s price alignment further indicates its integration with Austrian and German markets. Conversely, exchanges in the Western Balkans continue to experience substantial discounts due to their reliance on hydroelectric power, lower liquidity, and less effective market coupling mechanisms.
The observed intraday price volatility further emphasizes this structural divergence. On HUPX, hourly prices fluctuated dramatically, reaching a peak of 177.5 EUR/MWh and dipping to a low of 46.3 EUR/MWh. Similar spikes above 140 EUR/MWh were noted in Slovenia and Croatia, while SEEPEX and ALPEX also faced sharp hourly increases despite lower daily averages. In Albania, maximum hourly prices peaked at 163 EUR/MWh, illustrating how limited liquidity can exacerbate volatility when marginal units dictate pricing.
Total regional generation capacity reached 38,560 MW, with consumption recorded at 36,485 MW. The generation mix included 11,961 MW from hydro sources, 7,182 MW from coal, 5,877 MW from gas, 2,510 MW from wind, 3,194 MW from solar, and 5,539 MW from nuclear power. This dominance of hydro generation in several Balkan countries contributes to localized price suppression during stable water conditions; however, Hungary’s greater exposure to gas generation ties it more closely to carbon-adjusted pricing trends seen in Central Europe.
The net import balance for the SEE + Hungary system stood at -2,652 MW, with core imports of 177 MW primarily sourced from Austria and Slovakia. This dependency highlights the region’s need for external markets for balancing supply and demand during peak load periods. The current HU-DE spot spread of 13.7 EUR/MWh indicates active arbitrage opportunities as price differentials between Germany and Hungary promote cross-border trading optimization.
A key factor contributing to price fragmentation is liquidity asymmetry among the various exchanges. HUPX, BSP, and CROPEX benefit from deeper order books and stronger connections to EPEX markets that facilitate price convergence with continental hubs. In contrast, SEEPEX, BELEN, and ALPEX operate under thinner trading conditions where limited participation makes them more sensitive to fluctuations in generation output. The structural discounts seen in Serbia and Albania reflect enduring differences in market design rather than temporary cyclical phenomena.
The increasing penetration of renewable energy sources adds further complexity to the market dynamics. Total combined output from wind and solar reached 5,704 MW, which can depress midday prices in southern markets while increasing volatility during evening ramp-up periods. With thermal units maintaining an installed capacity of approximately 13,600 MW, there remains a significant reliance on dispatchable generation to ensure system stability. As renewable capacity continues to grow, intraday price spreads are expected to widen rather than narrow, emphasizing the importance of flexible assets and cross-border transmission capabilities.
The pricing landscape observed on February 25 illustrates a multi-layered regional structure: Central European-linked markets cluster around the 100 EUR/MWh threshold; intermediate markets such as Romania and Greece clear within the 50–60 EUR/MWh range; while exchanges in the Western Balkans consistently show structural discounts. Although these tiers are interconnected, they are not fully harmonized due to ongoing transmission bottlenecks and varying rates of renewable energy integration.
This configuration allows for persistent arbitrage opportunities across multiple corridors. The significant differential between HUPX at 107.7 EUR/MWh and SEEPEX at 53.6 EUR/MWh, exceeding 50 EUR/MWh, highlights potential inefficiencies within the market structure. Meanwhile, ALPEX’s discount of over 60 EUR/MWh relative to Hungary suggests either oversupply or structural isolation within that market segment.
The broader context indicates that SEE spot markets function as a semi-integrated system linked to Central Europe but still affected by local hydro resources and renewable energy output alongside transmission constraints. Until comprehensive flow-based coupling and enhanced balancing harmonization are achieved, price dispersion will remain a characteristic feature of the regional trading environment.
The data from February 25 serves as a reflection of an evolving energy landscape—one that is partially aligned with EU market structures yet remains internally segmented. As carbon pricing influences dispatch economics and renewable integration deepens further volatility is anticipated across SEE spot markets, underscoring the importance of cross-border spread analysis and system balance forecasting as essential elements for participants navigating this complex trading environment.
