On February 25, 2026, Hungary’s HUPX market cleared at 107.7 EUR/MWh, closely mirroring Central European price levels, while Slovenia’s BSP recorded a price of 100.4 EUR/MWh. This alignment indicates that markets closely linked to EU hubs are increasingly influenced by continental pricing dynamics driven by factors such as gas prices, carbon costs, and cross-border congestion. The price movements in Germany, transmitted through Austria and Slovakia, are now directly impacting clearing prices in Hungary and Slovenia, extending the influence of EU pricing further east.
Despite this integration, SEE markets remain vulnerable to volatility without ensuring uniform price outcomes across the region. While Hungary and Slovenia quickly reflect EU price signals, countries like Romania, Greece, and those in the Western Balkans continue to experience significantly lower clearing prices. On the same day, Romania’s OPCOM settled at 59.0 EUR/MWh, Greece’s HENEX at 54.5 EUR/MWh, SEEPEX at 53.6 EUR/MWh, BELEN at 54.5 EUR/MWh, and ALPEX at 45.5 EUR/MWh. This persistent discount of 40–60 EUR/MWh relative to EU-aligned hubs illustrates how the integration of spot exchanges transmits price pressures unevenly.
The underlying cause of this asymmetry is rooted in liquidity concentration within EU exchanges such as EPEX, which establish reference prices through high trading volumes and informational dominance. The depth of liquidity and sophisticated trading behaviors in these markets enable efficient marginal price discovery. In contrast, SEE exchanges often rely on indirect absorption of these signals through cross-border flows rather than direct coupling with EU prices. Consequently, fluctuations in EU prices predominantly affect SEE markets during peak demand hours or under constrained conditions.
The dynamics are further highlighted by the HU–DE spot spread of 13.7 EUR/MWh observed on February 25. This spread indicates that full convergence between Hungary and Germany is limited by transmission constraints and local system conditions. For southern markets, this attenuation is even more pronounced; EU prices frequently act as a ceiling rather than a reference for clearing prices.
Intraday volatility patterns have also been reshaped by exposure to EU exchanges. On HUPX, hourly prices peaked at 177.5 EUR/MWh, reflecting stress patterns similar to those seen in Germany and Austria. In contrast, Balkan markets displayed flatter intraday curves but experienced sharp spikes when marginal units were activated; for instance, Albania recorded a maximum hourly price of 163 EUR/MWh despite a base price of 45.5 EUR/MWh.
The generation mix plays a critical role in mediating the transmission of EU price dynamics within SEE markets. On February 25, hydro generation reached 11,961 MW across the Balkans, providing stability during periods of stress by offering low-marginal-cost supply that mitigates EU-driven price spikes. Where hydro resources are abundant, the impact of EU price signals is softened; conversely, regions with limited hydro capacity face increased exposure to volatility.
Thermal generation further links SEE markets to EU exchanges through coal and gas outputs of 7,182 MW and 5,877 MW respectively in Hungary, Romania, and Bulgaria. These thermal units are directly affected by EU fuel and carbon market conditions, leading to an importation of cost structures even when local spot prices remain discounted.
Renewable energy sources such as wind and solar also contribute to this interconnectedness; on February 25, their combined output reached 5,704 MW in SEE markets. This variability aligns intraday pricing patterns with those seen in EU markets—solar generation leads to midday price suppression while evening ramp-ups reflect continental trends.
The structural impact on market behavior is significant as utilities and traders in SEE increasingly reference EU hubs for bid formation and risk management. Even in regions with lower spot prices, market expectations are shaped more by EU trajectories than by domestic fundamentals alone.
As integration deepens, it also heightens exposure to external shocks from weather events or disruptions in Western Europe’s nuclear or gas supplies—these shocks can rapidly propagate into Hungary and beyond into SEE countries. The net import position of -2,652 MW recorded on February 25 underscores the region’s growing dependency on upstream conditions.
This complex exposure yields uneven consequences: markets closer to EU hubs enjoy benefits such as enhanced liquidity and transparency but face elevated price levels; peripheral markets maintain lower average prices yet encounter sharper episodic volatility when subjected to stress from EU-driven conditions.
The influence of EU spot exchanges on SEE power markets manifests along three key dimensions: establishing reference prices, transmitting volatility selectively through interconnections, and redistributing risk towards markets with weaker liquidity buffers. This evolving landscape indicates that SEE’s integration into EU spot markets represents not merely a binary transition but a nuanced reconfiguration of influence—EU exchanges now set upper pricing boundaries while local factors continue to dictate average outcomes.
In conclusion, while deeper coupling and expanded cross-border capacity may eventually bridge existing gaps between these interconnected systems, disparities in generation mixes and liquidity profiles will likely ensure that EU spot exchanges remain dominant transmitters rather than unifying forces for the foreseeable future. Understanding these dynamics is essential for stakeholders navigating the complexities of power trading within this evolving landscape.
