SEE day-ahead power prices jump as imports thin and wind output rebounds

South East European day-ahead electricity markets moved higher for delivery on 13 May, a shift that matters for both utilities and traders because it reflects a changing balance between cross-border supply, renewable variability and intraday flexibility needs. Regional pricing was pushed upward by collapsing imports from CORE European markets, tighter interconnection spreads and stronger evening balancing pressure.

Benchmarks rise, Serbia stays comparatively discounted

Hungary’s HUPX climbed to €136.54/MWh, while Romania’s OPCOM reached €137.18/MWh—both marking the highest regional benchmark levels among the monitored SEE exchanges. Serbia’s SEEPEX remained comparatively insulated at €110.80/MWh, continuing the market’s relative discount versus Hungary and Romania.

Import compression reduces arbitrage pressure

The pricing move also aligns with 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; CORE-linked imports from Austria and Slovakia dropped sharply as well. With cross-border availability tightening, arbitrage pressure from Western and Central Europe eased materially.

Even so, incentives for continued eastward price support persisted: the Hungary–Germany spread remained elevated at roughly €23/MWh.

Wind returns to the driver’s seat after solar-heavy sessions

Generation fundamentals pointed 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 output.

Solar production fell by nearly 700 MW, while gas generation declined by approximately 576 MW. The figures suggest thermal operators were increasingly reducing daytime dispatch exposure under volatile intraday price structures.

Hydro supportive but not dominant; nuclear stable

Hydro conditions remained structurally supportive but did not dominate the mix. Hydro represented about 23% of regional generation, coal accounted for 15% and gas for 12%. Nuclear maintained a stable contribution near 2.8 GW.

In balancing terms, the market is shifting toward a regime where wind volatility is becoming the dominant short-term price driver during shoulder hours and evening ramps—rather than solar saturation.

Serbia edges up only marginally despite stronger region-wide benchmarks

Serbia’s pricing behavior stood out: even as regional benchmarks strengthened, SEEPEX increased only marginally by €0.2/MWh day-on-day. The source attributes this to continued local balancing stability, relatively resilient domestic generation positioning and weaker exposure to broader Central European volatility.

At the same time, Serbia remains structurally influenced by Hungarian pricing formation through regional flow mechanics and cross-border congestion economics. Commercial flow data continues to show heavy directional exports and imports around Hungary and Romania, while Serbia keeps active balancing exchanges with Bosnia, Croatia and Hungary.

Intraday curves show midday softness and sharper evening ramps

The hourly curve pattern across the region followed a familiar structure: midday solar suppression kept prices lower between roughly H13–H16, while evening ramp pricing intensified significantly toward H21–H24 across HUPX, OPCOM and CROPEX.

Romania again recorded the strongest evening spikes, with hourly prices approaching €290/MWh—an indication of continuing flexibility shortages within the regional balancing structure.

Spot strength not fully reflected in forwards; fuel signals remain muted

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.

Gas markets continued weakening: Austrian CEGH June contracts fell toward €21.5/MWh. The source links current spot strength more strongly to short-term system balancing and import compression than to structural fuel cost escalation.

EUA carbon contracts stayed relatively firm near €75.8/t, keeping pressure on coal generation economics across the region.

A transition toward summer volatility—and more emphasis on flexibility

Taken together, the broader structural picture points toward a more volatile summer transition phase in SEE. Wind output volatility, negative-price exposure in high-solar hours, declining thermal flexibility and tighter interconnection economics are beginning to reshape regional dispatch behavior—especially ahead of the first full summer season following negative pricing mechanisms introduced across parts of the SEE trading architecture, including Serbia’s evolving market integration framework.

Infrastructure moves reinforce flexibility-focused investment themes

The transition narrative is reinforced by several infrastructure developments announced across the region: 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; Hungary’s E.ON completed a €322 million grid modernization program focused heavily on renewable integration capacity; Romania accelerated both PPA-driven renewable deployment and gas-processing industrial incentives tied to future Black Sea production growth.

For traders and utilities, this configuration increasingly rewards flexibility rather than baseload positioning alone. Battery energy storage systems (BESS), fast-ramping hydro resources, interconnection optionality and more sophisticated intraday optimization are becoming central revenue drivers—while widening divergence between midday and evening pricing profiles raises capture-price risk management needs for renewable operators during the remainder of 2026.