Southeast European electricity and gas markets entered a more fragmented pricing environment during April 2026. Wholesale electricity benchmarks across continental Europe moved sharply lower month-on-month, while gas markets remained structurally tight despite a temporary easing in spot prices. Regional data indicate that SEE power pricing is balancing weaker spring demand, stronger renewable generation, persistent cross-border congestion, and elevated carbon and gas risk premiums that continue to shape forward curves.
Across Europe, power markets corrected broadly in April following earlier extreme volatility. Average wholesale prices across 16 major exchanges fell by an average 14.89% month-on-month, while remaining 18.73% higher year-on-year. The figures point to seasonal normalization occurring alongside structurally elevated power pricing levels.
Regional electricity pricing stays supported by Italy premium
In Southeast Europe, the key signal was the relative resilience of regional prices versus Western Europe. Italy remained the highest-priced major market at €119.47/MWh. SEE-linked exchanges including Greece, Slovenia, Bulgaria, and Romania stayed within a high €88–96/MWh band during the month.
The regional price structure continues to reflect tighter conditions in Southeast Europe than in other parts of the continent. Hydrology volatility, thermal fleet limitations, interconnection bottlenecks, and reliance on imported marginal generation are cited as factors supporting elevated market clearing prices. Within this framework, Italy continues to act as the dominant anchor for SEE pricing formation.
Italian PUN averaged €119.47/MWh, remaining substantially above Germany at €78.52/MWh and France at an average of €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 electricity price of €88.72/MWh, down 6.61% month-on-month. Bulgaria’s IBEX averaged €90.99/MWh, Romania’s OPCOM reached €95.55/MWh, and Slovenia’s South Pool averaged €94.89/MWh. These levels indicate SEE pricing remains materially above Iberia and France even when renewable penetration is strong elsewhere.
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Cross-border spreads persist as volumes soften
The spread profile continued to support cross-border trading activity involving traders, balancing service providers, and battery storage operators. Persistent spreads between Italy and Central Europe, together with recurring Balkan transmission constraints, were reported to support congestion rents and volatility-driven arbitrage strategies.
Trading volumes showed a more cautious environment alongside the price correction. Greece’s HENEX traded volume fell by 23.3% month-on-month, while Romania’s OPCOM volumes dropped by almost 16%. The decline was associated with reduced industrial activity and weaker spring demand, alongside increased caution as fuel and carbon costs fluctuate.
Gas fundamentals tighten despite lower April spot levels
The broader European power market was also influenced by changes in fuel fundamentals during April 2026. Gas prices were lower month-on-month but remained historically elevated due to concerns over LNG availability, Middle East instability, and weak European storage entering the injection season .
The Dutch TTF day-ahead contract averaged €45.289/MWh during April, while Italy’s PSV day-ahead averaged €46.279/MWh. Both were described as substantially above long-term historical averages, sustaining elevated thermal generation costs across SEE electricity systems.
The structural issue in European gas was attributed to inventory weakness combined with geopolitical uncertainty rather than immediate supply scarcity. EU storage facilities entered the injection season at approximately 28%, compared with previous-year levels; Germany stood at 22%, while the Netherlands was at just 5%.
This inventory position is described as significant for Southeast Europe because regional gas infrastructure is relatively shallow and depends on imported flexibility. Any tightening in Northwest European LNG availability or Norwegian flows can translate into increased marginal pricing pressure across Balkan gas and electricity markets .
Norway flows, LNG geopolitics, and backwardation affect forward curves
Norway remains central to European gas stability through pipeline deliveries into Northwest Europe totaling 9.2 bcm in April. Deliveries were reported as broadly in line with the five-year average despite seasonal maintenance and several unplanned outages.
The strategic importance of Norwegian supply is expected to rise 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.
LNG pricing was shown to reprice rapidly during April as Asian buyers competed for cargoes while Europe attempted to refill depleted storage inventories simultaneously . The resulting market structure was described as problematic because forward curves show backwardation rather than encouraging seasonal storage injections.
The weakening of seasonal spreads reduces commercial incentives for traders and utilities to inject gas ahead of winter 2026/27 . For SEE electricity markets, this creates structural risk because gas-fired plants remain critical marginal balancing assets across Greece, Italy, Hungary, and parts of the Balkans.
Carbon costs support power prices; hydrology drives summer risk
If gas inventories do not rebuild sufficiently during summer, forward electricity prices for Q4 2026 and Q1 2027 could reprice sharply upward later in 2026 . Carbon markets add further pressure: EU Allowances remained above €70/tCO₂ during much of April.
The first official CBAM certificate benchmark price was set at €75.36/tCO₂. This was described as strategically significant for Southeast Europe because regional electricity systems are materially more carbon-intensive than Western Europe.
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