South East European day-ahead electricity markets moved sharply higher for delivery on 13 May, with regional pricing pushed upward by a combination of collapsing imports from CORE European markets, tighter interconnection spreads and stronger evening balancing pressure. Hungary’s HUPX climbed to €136.54/MWh, while Romania’s OPCOM reached €137.18/MWh, marking the highest regional benchmark among monitored SEE exchanges. Serbia’s SEEPEX remained comparatively insulated at €110.80/MWh, continuing the market’s relative discount versus Hungary and Romania.
The market structure increasingly reflects a regional decoupling pattern. Imports into the wider SEE and Hungarian region fell dramatically to only 220 MW net, down more than 2 GW day-on-day, while CORE-linked imports from Austria and Slovakia also dropped sharply. This tightening of cross-border availability materially reduced arbitrage pressure from Western and Central Europe. At the same time, the Hungary-Germany spread remained elevated at roughly €23/MWh, maintaining incentives for continued eastward price support.
Generation fundamentals show the system shifting back toward wind-supported balancing conditions after several solar-heavy trading sessions earlier in the week. Regional wind generation surged by more than 1.2 GW day-on-day to 3.37 GW, partially offsetting declines in gas-fired generation and reduced solar production. Solar output dropped by nearly 700 MW, while gas generation declined by approximately 576 MW, suggesting thermal operators are increasingly reducing daytime dispatch exposure under volatile intraday price structures.
Hydro conditions remain structurally supportive but not dominant. Hydro generation represented approximately 23% of the regional generation mix, while coal still accounted for 15% and gas 12%. Nuclear maintained a stable contribution near 2.8 GW. The balancing implication is increasingly clear: SEE markets are operating in a transition regime where wind volatility rather than solar saturation is becoming the dominant short-term price driver during shoulder hours and evening ramps.
Serbia’s pricing behavior remains notable. Despite stronger regional benchmarks, SEEPEX increased only marginally by €0.2/MWh day-on-day. This reflects continued local balancing stability, relatively resilient domestic generation positioning and weaker exposure to broader Central European volatility. However, Serbia remains structurally influenced by Hungarian pricing formation through regional flow mechanics and cross-border congestion economics. Commercial flow data continues showing heavy directional exports and imports around Hungary and Romania, while Serbia maintains active balancing exchanges with Bosnia, Croatia and Hungary.
Intraday hourly curves also reveal a familiar pattern emerging across the region. Midday solar suppression continues creating lower-priced hours between approximately H13-H16, while evening ramp pricing intensified significantly toward H21-H24 across HUPX, OPCOM and CROPEX. Romania again displayed the strongest evening spikes, with hourly prices approaching €290/MWh, underlining continuing flexibility shortages in the regional balancing structure.
Forward markets softened slightly despite stronger spot prices. Hungarian Week-21 contracts eased to around €124.5/MWh, while June and Calendar-2026 contracts also drifted lower. Meanwhile, gas markets continued weakening, with Austrian CEGH June contracts falling toward €21.5/MWh, suggesting that current spot strength is being driven more by short-term system balancing and import compression than by structural fuel cost escalation. EUA carbon contracts remained relatively firm near €75.8/t, maintaining continued pressure on coal generation economics across the region.
The broader structural picture across SEE increasingly points toward a market entering a more volatile summer transition phase. Wind output volatility, negative-price exposure in high-solar hours, declining thermal flexibility and tighter interconnection economics are beginning to reshape regional dispatch behavior. This dynamic becomes particularly important ahead of the first full summer season following the introduction of negative pricing mechanisms across parts of the SEE trading architecture, including Serbia’s evolving market integration framework.
Several strategic infrastructure developments announced across the region also reinforce this transition narrative. Montenegro advanced both the 64.8 MW Momce wind farm and a new partnership between EPCG and Japan’s PowerX targeting roughly 500 MWh of battery storage deployment, while Hungary’s E.ON completed a €322 million grid modernization program focused heavily on renewable integration capacity. Romania simultaneously accelerated both PPA-driven renewable deployment and gas-processing industrial incentives tied to future Black Sea production growth.
For traders and utilities, the current market configuration increasingly rewards flexibility rather than baseload positioning alone. BESS projects, fast-ramping hydro, interconnection optionality and sophisticated intraday optimization are becoming central revenue drivers. The widening divergence between midday and evening pricing profiles suggests that capture-price risk management will become materially more important for renewable operators across SEE during the remainder of 2026.