Southeast European electricity and gas markets moved into a more fragmented pricing environment during April 2026. Wholesale electricity benchmarks across continental Europe fell sharply month-on-month, while gas markets stayed structurally tight despite a temporary easing in spot prices. Regional data indicate that SEE power pricing increasingly reflects weaker spring demand, stronger renewable generation, persistent cross-border congestion, and elevated carbon and gas risk premiums affecting forward curves.
Across Europe, power markets saw a broad correction following earlier-year volatility. Average wholesale prices across 16 major exchanges declined by 14.89% month-on-month in April, while remaining 18.73% higher year-on-year. Despite the seasonal normalization, the figures point to continued structurally elevated power pricing.
Regional electricity benchmarks and price spreads
In Southeast Europe, the key signal was the relative resilience of regional prices versus Western Europe rather than only the monthly decline. Italy stayed the highest-priced major market at €119.47/MWh. SEE-linked exchanges including Greece, Slovenia, Bulgaria, and Romania remained in a high €88–96/MWh band.
The regional pricing pattern continues to align with tighter market conditions in Southeast Europe. Hydrology volatility, thermal fleet limitations, interconnection bottlenecks, and reliance on imported marginal generation are cited as factors supporting higher market clearing prices. The Italian market is described as the dominant anchor for SEE pricing formation.
Italian PUN averaged €119.47/MWh, staying well above Germany’s €78.52/MWh and France’s €39.80/MWh. The persistence of the Italy premium is linked to export economics for interconnected SEE generators, particularly during evening peak periods when solar output declines. Greece recorded an average wholesale price of €88.72/MWh, down 6.61% month-on-month.
Bulgaria’s IBEX averaged €90.99/MWh, while Romania’s OPCOM reached €95.55/MWh. Slovenia’s South Pool averaged €94.89/MWh. These levels indicate that SEE markets remained priced materially above Iberia and France even when renewable penetration was strong elsewhere in Europe.
Spread dynamics also remained central for market participants operating across borders. Persistent spreads between Italy and Central Europe, together with recurring Balkan transmission constraints, supported congestion rents and volatility-driven arbitrage strategies for traders and battery storage operators.
Trading volumes soften in Greece and Romania
While price levels held up relative to Western Europe, volumes showed a more cautious environment. Greece’s HENEX traded volume fell 23.3% month-on-month in April. Romania’s OPCOM volumes dropped by almost 16%.
The volume decline is associated with reduced industrial activity and weaker spring demand in the source data context. It also reflects increased caution among participants dealing with volatile fuel and carbon costs.
Gas fundamentals stay tight as storage enters injection season
The broader European power market was influenced by changes in fuel fundamentals alongside the electricity correction. Gas prices were lower month-on-month in April but remained historically elevated due to concerns about LNG availability, Middle East instability, and weak European storage heading into injection season.
The Dutch TTF day-ahead contract averaged €45.289/MWh during April, while Italy’s PSV day-ahead averaged €46.279/MWh. These levels were still described as substantially above long-term historical averages, supporting elevated thermal generation costs across SEE electricity systems.
The structural issue for European gas is framed as inventory weakness combined with geopolitical uncertainty rather than immediate supply scarcity. EU storage entered injection season at approximately 28% full, compared with lower levels cited for Germany at 22% and the Netherlands at just 5%. This is relevant for Southeast Europe because regional gas infrastructure is described as relatively shallow and dependent on imported flexibility.
Narrowing LNG availability or changes in Norwegian flows in Northwest Europe can quickly translate into marginal pricing pressure across Balkan gas and electricity markets . Pipeline deliveries into Northwest Europe totaled 9.2 bcm in April, broadly in line with the five-year average despite seasonal maintenance and several unplanned outages.
The strategic role of Norwegian supply is expected to increase as the EU moves toward a complete ban on Russian LNG imports by the end of 2026 and pipeline imports later in 2027 . At the same time, LNG markets remain exposed to geopolitical disruptions around the Strait of Hormuz and Qatar’s export infrastructure.
The source data describes April as another example of how quickly LNG pricing can reprice global gas systems. Asian buyers competed for cargoes while Europe attempted to refill depleted storage inventories concurrently . Forward curves were characterized as showing backwardation rather than patterns that would incentivize seasonal storage injections ahead of winter 2026/27.
Carbon pricing supports higher wholesale power across SEE
The gas-to-power linkage is described as a structural risk for SEE electricity markets because gas-fired plants remain critical marginal balancing assets across Greece, Italy, Hungary, and parts of the Balkans . If gas inventories do not rebuild sufficiently during summer, forward electricity prices for Q4 2026 and Q1 2027 could reprice upward later this year.
