Day-ahead electricity prices declined across most of Southeast Europe on 12 May, according to regional market data. Romania’s OPCOM remained the highest-priced venue at €127.9/MWh, followed by Hungary’s HUPX at €123.2/MWh. Serbia’s SEEPEX cleared at €110.6/MWh, while Greece’s HENEX fell to €79/MWh. Albania was again the lowest-priced market at €70.3/MWh.
The largest single-day adjustment was recorded in Bulgaria, where IBEX prices fell by almost €23/MWh. Slovenia, Austria and Greece also saw substantial decreases. The regional spread structure narrowed versus earlier sessions, while Hungary and Romania continued to trade at a premium relative to southern Balkan hubs. The premium was linked to ongoing congestion and structural import reliance in the north-eastern corridor.
Renewables output, demand and generation balance
The generation mix shifted from the previous day, with wind output rising sharply across the region. Regional wind generation increased to 2,121 MW, up by more than 1,400 MW day-on-day. Hydro output improved to 5,827 MW, and solar generation stayed above 5,100 MW. Nuclear production declined modestly as total regional generation reached 25.3 GW.
Consumption rose above 29.2 GW, leaving the region structurally short and reliant on imports. Imports into Southeast Europe and Hungary increased to around 2,461 MW net. Core inflows from Austria and Slovakia into Hungary and Slovenia rose significantly during the observed window. The data points to continued dependence on Central European liquidity and thermal generation when demand is elevated and renewables are intermittent.
Serbia’s import exposure and EPS dynamic pricing expansion
Serbia remained structurally import-dependent during the trading window despite reported improved corporate profitability for 2025. Commercial flows showed continued inflows from Bosnia and Herzegovina, Croatia and Hungary into the Serbian system. This reflected Serbia’s balancing exposure alongside still-large domestic coal generation.
A key structural change for Serbia is the expansion by EPS of dynamic pricing and exchange-linked contracts for industrial consumers. EPS is aligning commercial supply arrangements with SEEPEX signals using hourly-indexed, monthly-average and hybrid pricing models. The approach transfers part of market volatility to industrial customers while encouraging flexible consumption behavior and energy management systems.
The shift is particularly relevant for CBAM-exposed exporters in metals, chemicals, cement and manufacturing. Serbia’s electricity market is described as moving from a politically stabilized pricing environment toward a more market-exposed structure comparable with mature EU hubs. The change creates procurement risk alongside optimization opportunities for firms able to shift demand into lower-priced solar hours or use behind-the-meter storage. The dataset also references widening intra-day spreads and periodic negative-price events seen in neighboring EU markets.
Intraday price shapes across HUPX, OPCOM and HENEX
The hourly profiles published for HUPX, OPCOM and HENEX showed continued midday price compression linked to solar generation. Prices then moved into strong evening ramps across the same venues. Romania displayed the most pronounced volatility profile, with intraday prices reaching above €250/MWh during evening peak hours before dropping sharply during solar-rich periods.
Greece, meanwhile, showed some of the weakest midday pricing conditions in the region as its solar fleet expands. The broader pattern indicates that short-term volatility is not only tied to gas prices or geopolitical shocks. Instead, it is described as entering a renewable-shaping phase where solar saturation, evening balancing scarcity, cross-border congestion and hydro variability influence day-to-day pricing behavior.
Weather outlook, gas-carbon signals and forward curves
Temperatures are expected to decline across Serbia, Romania, Bulgaria and Hungary over the next several days, according to forecasts cited in the dataset. The expected cooling-demand reduction is paired with conditions that support renewable integration. Gas and carbon markets were described as relatively stable but supportive for power pricing.
CEGH gas traded around €47/MWh, while EU carbon allowances rose toward €77/tCO₂. Coal-fired generation cost pressure in Southeast Europe remains linked to those levels, particularly in Serbia and Bosnia where coal continues to dominate supply structures. In the regional generation balance for the observed period, coal accounted for around 17%, while gas contributed approximately 15%.
Forward markets showed resilience despite weaker spot prices, with Hungarian Week 21 baseload futures trading around €127.5/MWh. Calendar 2026 contracts remained above €113/MWh, indicating continued pricing of structural tightness into regional curves despite renewable-driven spot corrections.
Southeast Europe hybrid projects and gas corridor constraints
The dataset also highlights growing links between renewables, industrial demand and storage infrastructure across Southeast Europe. New project announcements from Bulgaria, Greece and Turkey point to hybrid structures combining renewables, storage and industrial decarbonization measures. A Bulgarian partnership between CWP Europe and Heidelberg Materials pairs wind generation with low-carbon cement production using carbon-neutral materials.
A Turkey project using Goldwind turbines combines wind with storage as part of a hybrid development described as supporting storage-backed renewable flexibility. At the same time, the gas market outlook is described as fragile for buyers considering long-term commitments. The Vertical Gas Corridor connecting Greece toward Ukraine is reported to be struggling with insufficient commercial demand despite revised tariff structures and operational flexibility.
The dataset further notes that buyers remain reluctant to commit to long-term capacity while Russian gas still indirectly enters regional markets and LNG demand remains uncertain.