Electricity prices across most Southeast European markets moved materially lower between 11–17 May 2026, with the change attributed to a sharp expansion in wind generation, softer seasonal demand, and reduced thermal dispatch. Week 20 also reflected a shift in how regional power is priced, with renewables increasingly influencing short-term marginal levels while gas volatility and cross-border balancing affect trading behaviour.
The largest weekly price corrections were recorded in markets previously exposed to higher balancing and thermal costs. Greece saw average wholesale prices fall -17.9% week-on-week to €87.25/MWh, while Serbia declined -12.5% and Italy dropped -11.6%. Italy still remained the most expensive major SEE market at €116.22/MWh.
Wind and variable renewables drive lower marginal pricing
Total variable renewable output across SEE increased +27.0% week-on-week to 3.60 TWh. Wind generation rose +57.4% regionally during the same period, contributing to the downward pressure on marginal pricing across interconnected Balkan systems.
The data indicates that renewable-driven repricing is becoming more than a seasonal effect. The pattern was reinforced by market changes linked to wind conditions improving across the region.
Serbia: wind increase alongside hydropower collapse and higher imports
Serbia provided one of the clearest examples of the transition during Week 20. The country recorded one of the strongest percentage increases in wind production, while hydropower output fell by -49.4%.
The combination coincided with a sharp rise in Serbian net imports, which increased +251.2% week-on-week even as domestic wholesale prices declined materially. The shift points to growing reliance on balancing between intermittent wind output and reduced hydro flexibility.
Serbian balancing has historically depended on lignite baseload together with hydro flexibility from the Drina and Danube systems. With regional wind generation growing, intraday market structure is changing, and improved wind conditions across the Balkans can make cross-border electricity cheaper and more available, reducing the competitiveness of domestic thermal dispatch.
Thermal output declines as gas-linked pricing remains a key factor
Across SEE, thermal generation fell -13.7% week-on-week to 4.12 TWh. Gas-fired output alone decreased by -15.5%, aligning with lower dispatch needs during the period.
Greece showed further pressure on conventional generation, with Greek lignite production down more than -30% week-on-week. Italy, despite improved renewable conditions, averaged more than €116/MWh, remaining among the highest-priced major markets in Europe.
This pricing pattern reflects continued exposure to gas costs in systems with higher gas dependency, where prices trade at a persistent premium relative to renewable-heavy areas. For SEE power markets, gas volatility remains tied to how electricity prices move during periods of lower renewable output.
Regional flows intensify; Bulgaria exports while Türkiye stays low-priced
Cross-border trading intensified during Week 20, with total net imports across SEE increasing +51.0% week-on-week to 1.56 TWh. Bulgaria shifted from net importer to strong net exporter during the week, supported by improved generation competitiveness.
Bulgaria’s role within regional electricity flows strengthened further as it became one of the most important balancing corridors between Romania, Greece, Türkiye, Serbia, and Central Europe. Türkiye continued to operate as an outlier market, with Turkish electricity prices averaging only €13.21/MWh, well below EU market levels.
TTF rises above €50/MWh amid storage refill concerns
The gas market introduced a counterbalancing risk for power pricing in the region as European TTF climbed back above €50/MWh. The move was supported by tightening LNG fundamentals, geopolitical uncertainty around Middle East supply routes, and stronger Asian LNG demand expectations.
Dutch TTF futures recorded a weekly gain of approximately 4.8%, while prices rose more than 22% over the past month and over 33% year-on-year. Gas pricing continues to influence Italian, Greek, Hungarian, and partially Croatian power pricing structures.
A separate risk highlighted for Europe is insufficient gas storage refill economics. European gas inventories were about 7.2 bcm lower than last year’s levels, or around 17%, largely due to elevated prompt pricing and backwardated TTF curves discouraging injections into storage.
If those conditions persist through summer, Europe may enter winter 2026/27 with materially weaker storage buffers than policymakers originally expected. Gas volatility is expected to feed into power price volatility in SEE electricity markets during low renewable production periods.
A three-zone pricing structure emerges across coupled markets
The market is increasingly fragmenting into three structural pricing zones based on generation mix and gas exposure. The first zone includes low-cost renewable-dominant systems such as France and Spain, and increasingly Greece during strong solar periods.
The second zone covers transition markets including Serbia, Bulgaria, Romania, and Croatia, where renewable growth is changing dispatch structures but thermal generation still retains balancing importance. The third zone consists of structurally gas-exposed systems such as Italy and parts of Central Europe where gas pricing continues to dominate marginal electricity pricing.
This transition is relevant for project bankability assessments for investors, lenders, and industrial electricity consumers seeking long-term supply arrangements aligned with evolving market conditions. Renewable assets able to demonstrate hourly matching, cross-border delivery capability, battery flexibility, traceable Guarantees of Origin using SCADA traceability and hourly matching structures are expected to attract materially stronger financing conditions over the next investment cycle.
The trend is particularly visible in Serbia and Montenegro where future export-oriented industrial investments are being evaluated not only on labor cost or logistics efficiency but also on long-term availability of verifiable low-carbon electricity.
The Week 20 market data also underlines that Southeast Europe is functioning as a transition corridor for renewable balancing and cross-border power trading alongside industrial decarbonization and CBAM-linked electricity sourcing.