Regional Southeast European electricity markets moved into a more balanced trading configuration for delivery on 21 May 2026, with stronger renewable generation reducing regional import dependence. The session also coincided with major price divergence between northern and southern SEE markets.
Wind and solar drive the daily balance
The largest shift in the daily balance came from a sharp expansion in wind generation across the SEE region. Total wind production surged to 4,073 MW, up by 2,351 MW day-on-day, becoming the single largest balancing factor behind the collapse in net imports.
Regional net imports fell to just -868 MW, compared with import requirements exceeding 900 MW earlier in the week. At the same time, solar output remained exceptionally strong at 5,949 MW.
Hydro generation continued to contribute a substantial 6,952 MW, although it declined by 443 MW from the previous day. The combined renewable stack displaced gas-fired generation, which dropped by more than 1,180 MW day-on-day to only 2,646 MW.
Spot pricing diverges across SEE markets
The renewable-heavy mix continued to influence pricing behavior across the region. Serbian SEEPEX prices stayed among the lowest in Europe at €66.56/MWh, despite a modest daily increase.
Albania’s ALPEX fell to €57.87/MWh, reported as the lowest price in the region and almost €49/MWh below Italian prices. The broader structure showed widening north-south divergence, with Italy trading at €115.37/MWh and Germany at €109.15/MWh.
The Greek market recorded one of the most volatile moves of the session. HENEX rose almost 24% day-on-day to €90.99/MWh, linked to tighter balancing conditions in the southern Balkans and persistent interconnection constraints toward Italy.
Midday solar effects and cross-border flows
Hourly curves across Central Eastern Europe reflected deep solar cannibalization during midday hours. Romanian OPCOM, Slovenian BSP and Austrian EPEX all recorded extremely weak intraday midday pricing.
Romania briefly moved into negative territory, with a minimum hourly pricing level of -€6.5/MWh. In regional spreads, the Hungarian-German spread narrowed to approximately -€2.5/MWh.
Cross-border commercial flows also reflected changes in internal SEE balancing. Romania remained the dominant exporter toward Hungary with average commercial flows exceeding 1,300 MW, while Greece operated as the region’s largest net importer with imports above 1,000 MW.
Renewable discounts, GO integration, and forward market softness
The Serbian market continued to show a renewable-driven discount structure. SEEPEX average prices remained nearly €40/MWh below Italian levels.
The same pricing gap was described as supporting energy-intensive industrial demand and future green industrial development tied to CBAM-sensitive exports. As EU CBAM implementation accelerates, low-priced renewable-heavy systems in Serbia, North Macedonia, Albania and parts of Bosnia were cited as becoming structurally more attractive for steel, aluminium, chemicals and processing sectors supplying the EU market.
Narrative on guarantees of origin and MEMO membership
North Macedonia’s integration into the European Guarantees of Origin ecosystem through MEMO’s full AIB membership was highlighted as a strategically important development for regional electricity markets. The change was described as strengthening bankability for renewable PPAs and cross-border green electricity verification mechanisms in the Western Balkans.
The development was also linked to industrial buyers seeking fully traceable renewable electricity sourcing under CBAM-related procurement frameworks. It was noted that expansion of GO systems across the region may support higher-quality renewable pricing structures rather than simple merchant exposure.
Gas prices steady; forward curves soften across hubs
Forward curves softened across most Central European power hubs. Hungarian Week 22 baseload contracts declined to approximately €102.5/MWh, while German forward power weakened alongside falling gas and coal forwards.
Austrian CEGH gas traded around €51.66/MWh, while EUA carbon prices held near €75.4/t. Despite ongoing geopolitical tension around global shipping routes, gas fundamentals were described as relatively stable.
Thermal displacement and summer 2026 volatility outlook
The combination of lower imports, stronger renewable penetration and weaker thermal utilization was described as reinforcing a structural transition across SEE electricity systems. Thermal generation activation remained relatively subdued despite stronger weekday demand.
This pattern suggested that renewable penetration increasingly displaced conventional balancing units during daylight hours. The evolving structure was expected to intensify price volatility through summer 2026 in markets including Romania, Bulgaria and parts of former Yugoslav systems.
Grid digitalization and new demand signals in SEE infrastructure
The investment narrative also shifted toward grid digitalization, balancing infrastructure and flexible generation. Serbia’s expanding cooperation between EDS and EDF on smart grids and automation was cited as reflecting a broader focus on digital balancing capability for renewable integration.
The Croatian Pantheon AI data center project was also referenced as signaling future electricity demand growth in SEE infrastructure markets. Planned demand of approximately 1 GW for the AI campus alone is supported by dedicated renewable procurement and new 400 kV transmission infrastructure.
