On February 25, 2026, Hungary’s HUPX exchange reported a clearing price of 107.7 EUR/MWh, closely mirroring Central European price levels. Slovenia’s BSP followed with a price of 100.4 EUR/MWh. This alignment indicates that markets with strong connections to EU hubs are beginning to internalize pricing mechanisms influenced by gas, carbon costs, and cross-border congestion. The price dynamics originating in Germany are now directly impacting clearing prices in Hungary and Slovenia, effectively pushing the EU core pricing zone further eastward.
Conversely, the transmission mechanisms that link these markets also expose them to significant volatility without ensuring uniformity in pricing outcomes. For instance, 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 approximately 40–60 EUR/MWh compared to EU-aligned hubs highlights the asymmetric nature of price transmission within the region.
The underlying cause of this asymmetry is primarily attributed to liquidity concentration within EU markets. Exchanges like EPEX not only establish reference prices through transaction volume but also benefit from greater informational dominance and participant sophistication. In contrast, SEE exchanges often operate with limited liquidity and depth, absorbing signals from EU markets indirectly through cross-border flows rather than direct coupling. Consequently, fluctuations in EU prices tend to impact SEE markets mainly during peak demand periods or under constrained conditions.
The observed HU-DE spot spread of 13.7 EUR/MWh on February 25 illustrates this dynamic further; it signals that even between Hungary and Germany, full convergence is hindered by local transmission constraints and system conditions. For southern markets in particular, the attenuation of these influences is more pronounced as EU spot prices tend to act as a ceiling rather than a consistent reference for daily averages.
Moreover, intraday volatility is being 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—while Balkan markets exhibited flatter curves interspersed with sharp spikes during peak demand periods. For example, Albania recorded a maximum hourly price of 163 EUR/MWh against a base price of 45.5 EUR/MWh on that day.
Generation mix also plays a crucial role in mediating these dynamics; hydro generation reached 11,961 MW on February 25 and acted as a stabilizing force across Balkan systems by providing low-marginal-cost supply during high-stress periods. However, where hydro resources are scarce, exposure to volatile price signals increases significantly.
Thermal generation remains another critical link between SEE markets and EU exchanges with coal output at 7,182 MW and gas output at 5,877 MW anchoring marginal pricing in Hungary, Romania, and Bulgaria. These thermal units are directly influenced by EU fuel and carbon pricing mechanisms even when local spot prices remain lower.
The integration of renewables has intensified this linkage further; wind and solar generation totaled 5,704 MW on February 25, introducing variability that aligns intraday patterns in SEE with those occurring in EU markets. The midday suppression of solar-driven prices followed by evening ramp-up stresses reflects broader continental trends.
As market behavior continues to evolve structurally within SEE regions, utilities are increasingly referencing EU hubs for bid formation and risk management strategies despite lower local spot prices. This shift signifies a transition from inward-focused balancing systems toward more outward-looking platforms driven by external reference points.
However, this integration also heightens vulnerability to external shocks such as weather events or disruptions in gas supply from Western Europe which can quickly propagate into the SEE region’s energy landscape—illustrated by a net import position of -2,652 MW on February 25.
The consequences of this exposure vary across the region; while markets closest to EU hubs benefit from enhanced liquidity and transparency alongside arbitrage opportunities at higher prices, peripheral markets maintain lower average prices yet experience heightened episodic volatility when pressures from the EU market penetrate through limited interconnectors.
In summary, the influence of EU spot exchanges is fundamentally reshaping SEE power markets along three critical dimensions: establishing new reference prices; selectively transmitting volatility; and redistributing risk toward less resilient markets with thinner liquidity profiles. This ongoing integration process does not represent an all-or-nothing shift but rather reflects a gradual reweighting of influences where local conditions still play a vital role in determining average outcomes amidst deepening ties with European power structures over time.
