SEE power markets moved into a sharply diverging pricing structure on 15 May 2026, with Central European markets remaining structurally elevated above €110/MWh, while parts of the Western Balkans experienced an aggressive price collapse driven by weaker regional demand, lower import dependency and improving hydrological conditions.
The most important market signal of the day was the extreme decoupling between SEEPEX Serbia and the broader HUPX-linked regional complex. Serbian day-ahead prices collapsed to €65.79/MWh, down almost €49.5/MWh day-on-day, making Serbia the lowest-priced market in the region by a very wide margin. Montenegro followed at €93.41/MWh, while North Macedonia traded at €83.18/MWh and Albania at €90.11/MWh. By contrast, Slovenia, Croatia, Romania and Hungary remained tightly coupled around the €117–120/MWh range.
This pricing fragmentation reflects a temporary but important structural divergence in regional power balances. Serbia benefited from significantly stronger domestic generation and lower import dependency, while northern and core-linked markets remained exposed to tighter coupling with Italian and Central European pricing. The report shows total regional imports collapsing to only 167 MW, down nearly 950 MW versus the previous day, indicating a substantial reduction in external balancing needs across the SEE region.
The generation mix explains much of the move. Regional hydro output remained strong at 6,404 MW, accounting for around 24% of the power mix, while coal generation increased to 4,876 MW and gas-fired generation rose to 3,736 MW. At the same time, wind production collapsed by almost 1,800 MW day-on-day, falling to 1,897 MW.
Normally, such a sharp wind decline would support higher prices across SEE markets. Instead, the combination of stronger hydro availability, reduced imports and softer demand offset the loss of wind generation. Regional consumption increased modestly to 28,694 MW, but remained manageable within the existing thermal-hydro mix.
The Serbian market displayed the clearest example of local balancing pressure overwhelming regional pricing convergence. SEEPEX hourly prices remained heavily discounted through most of the day, with a minimum price of €30/MWh and peak values only reaching €121.1/MWh. The Serbian spread versus HUPX widened dramatically, creating one of the strongest arbitrage signals seen in recent weeks across the Balkan corridor.
Cross-border commercial flow data also confirmed persistent export orientation from several SEE markets toward neighboring deficit systems. Hungary maintained strong exports toward Croatia and Austria, while Romania exported heavily toward Hungary. Greece remained structurally import-dependent from Bulgaria, with average commercial flows from Bulgaria into Greece reaching approximately 987 MW in base load terms over the previous seven days.
Another major driver remained Italian pricing strength. Italy traded at €136.36/MWh, retaining its position as the highest-priced market in the monitored region. This continued to support northwestern SEE markets such as Slovenia and Croatia through coupled flow dynamics and export economics into the Italian system.
Forward markets meanwhile remained relatively stable despite the sharp spot volatility. Hungarian week-ahead baseload contracts traded around €117/MWh, while calendar 2026 power remained above €112/MWh. EUA carbon prices stayed elevated at around €75/t, while CEGH gas traded near €49/MWh. This indicates traders still view the current spot weakness in Serbia and parts of the Balkans as temporary rather than structural.
The underlying thermal system remains active. Activated thermal generation capacity across the region stayed elevated through the week, while Danube hydrology conditions improved materially, supporting hydro dispatch flexibility. This combination is increasingly important for balancing growing renewable penetration across SEE markets, particularly as solar generation continues expanding rapidly across Hungary, Romania, Greece and Serbia.
From a structural market perspective, the data again highlights the growing fragmentation inside SEE electricity pricing after the introduction of negative-price capable market structures earlier in 2026. While the region remains increasingly interconnected physically, local renewable surpluses, hydro variability and transmission bottlenecks are creating wider temporary pricing dislocations between neighboring markets.
This is particularly important for battery storage developers, cross-border traders and industrial offtakers. The spread between Serbia at €65.79/MWh and Italy at €136.36/MWh represents an intraregional differential exceeding €70/MWh in a single trading session. Such spreads materially improve the economics of cross-border balancing assets, storage arbitrage and flexible industrial demand management.
The investment and infrastructure news flow across the region also reinforced the accelerating buildout of renewable and grid infrastructure. Kosovo’s 72 MW Zatriq wind farm is approaching commissioning, Romania’s 99 MW Green Breeze wind project entered final commissioning, while Turkey continues expanding both wind generation and underground gas storage capacity.
At the same time, Serbia’s EPS reported a quarterly profit of €129 million, supported by stronger hydrology, higher coal production and reduced debt levels. That combination reinforces the importance of legacy thermal-hydro systems in stabilizing SEE markets during periods of renewable volatility.
The daily data points to a market increasingly shaped by short-duration renewable swings, hydro conditions and congestion-driven fragmentation rather than purely fuel-driven pricing logic. The widening divergence between local Balkan pricing and core European markets is becoming one of the defining structural characteristics of SEE electricity trading in 2026.