Day-ahead electricity prices across Southeast Europe and Hungary rose on Thursday, marking a clear reversal from the softer tone seen in parts of the southern region the previous day. The move was closely tied to evening system dynamics, with Hungary again acting as the marginal pricing reference point for the area. For grid planners and storage developers, the pattern reinforces how ramping conditions can quickly translate into price volatility.
Hungary sets the regional ceiling
Hungary’s HUPX day-ahead baseload jumped to €123.77/MWh, up €20.6/MWh day on day, the highest level recorded across the region. Prices elsewhere were more clustered, with Romania and Bulgaria at €103.02/MWh, Serbia at €101.45/MWh, Greece at €101.23/MWh, and Albania at €99.78/MWh. Further north-west, Slovenia reached €116.39/MWh and Croatia €112.10/MWh, while Montenegro remained the lowest-priced market at €92.79/MWh.
The rebound occurred even as demand growth stayed limited. Total consumption across SEE and Hungary was forecast at 34,847 MW, only slightly above Wednesday levels. This combination points to a generation-mix reshuffle and continued reliance on external supply during peak periods rather than a broad-based tightening from demand alone.
Wind adds incremental supply, but other sources soften
Wind generation delivered the largest incremental contribution, rising sharply to 5,244 MW, an increase of 1,590 MW day on day. Total generation in the region increased to 36,010 MW as a result of this wind uplift. However, it was partially offset by weaker output elsewhere: gas-fired generation fell to 5,208 MW and solar declined to 3,161 MW.
Hydropower output also eased to 7,304 MW. For developers assessing renewable integration pathways, the figures highlight that even sizable wind gains may not fully counterbalance declines in dispatchable or weather-dependent resources within the same operating window.
Import dependence deepens during peak stress
Despite stronger renewable contribution, Southeast Europe remained structurally import-dependent. Net imports deepened to -2,067 MW compared with -1,255 MW the previous day, indicating that improved wind conditions were not sufficient to displace external flows entirely. This operational reality matters for transmission planning because cross-border balancing needs can persist even when local renewables strengthen.
Cross-border pricing signals also remained supportive of west-to-east flows. Hungary’s premium over Germany narrowed but stayed positive as the HU-DE spread tightened to €10/MWh from €14.2/MWh on Wednesday. At the same time, imports from the CORE region dropped to 200 MW from 1,350 MW a day earlier, suggesting changes in how balancing is sourced rather than a reduction in overall import requirements.
Evening price volatility underscores flexibility requirements
Hourly price structures underlined the importance of evening system stress across markets. Most locations saw peak prices around hour 20, consistent with the post-solar ramp profile that typically tightens system balance later in the day. In Serbia, SEEPEX prices ranged from a minimum of €35/MWh to a maximum of €175/MWh.
Hungary showed markedly higher volatility than its neighbours, with prices spanning from €4.7/MWh at the low end to €254.1/MWh at the peak. For battery energy storage systems and flexible generation portfolios, such swings are central to revenue modelling because they reflect both scarcity moments and fast-changing marginal supply conditions.
Forward curve remains elevated
Forward markets continued to support expectations consistent with current tightness dynamics. Hungarian weekly and monthly contracts priced elevated levels including Week 13 at €116.5/MWh and Week 14 at €99.5/MWh, while April-26 stood at €101/MWh and Cal-26 at €110.5/MWh. Forward spreads versus Germany also remained positive across the curve.
Fuel-side signals were comparatively muted during the session. CEGH gas prices edged up to €54.38/MWh and EU carbon allowances slipped slightly to €65.87/t, limiting directional impact on power pricing relative to operational factors like ramping and import sourcing.
Storage expansion and thermal build reflect execution readiness needs
The market backdrop aligns with ongoing infrastructure development aimed at increasing flexibility capacity in the region. Hungary is expanding battery storage through Alteo’s addition of a new 10 MW unit, bringing its installed portfolio to 80 MW—an indicator that project execution is moving beyond planning into capacity delivery readiness for grid services.
Romania is also progressing new thermal capacity with multiple bids received for a 275 MW cogeneration plant, reflecting continued procurement activity tied to dispatchable output needs alongside renewables growth. In Bulgaria, policy discussions around EU ETS participation point to unresolved tensions between decarbonisation targets and industrial competitiveness—an issue that can influence permitting timelines and investment bankability for both generation and supporting networks.
Broader implications: Thursday’s price rebound shows controlled firmness rather than outright scarcity—wind improved supply conditions but steep evening ramps and persistent import dependence kept prices elevated. For utilities and industrial stakeholders planning renewable build-out alongside grid modernization and BESS deployment, the pattern reinforces why technical studies must model hourly ramp stress closely and why EPC preparation should account for flexibility-driven operating conditions rather than relying solely on average-day demand or renewable output forecasts.