Day-ahead electricity markets across Southeast Europe moved sharply higher for delivery on 22 May 2026, with most regional hubs recording strong rebounds after softer solar-driven pricing earlier in the week. The move was led by tightening renewable generation balances, rising import dependence, and widening evening scarcity premiums across Central and Eastern Europe.
Hungary’s HUPX closed at €116.02/MWh, up 9.3% day-on-day, re-establishing itself as the highest-priced major market in the region. Romania’s OPCOM followed at €111.89/MWh, while Croatia’s CROPEX settled at €110.08/MWh and Slovenia’s BSP at €109.28/MWh. Bulgaria’s IBEX reached €103.82/MWh, while Greece’s HENEX remained structurally lower at €92.38/MWh due to stronger domestic renewable balancing and lower marginal thermal pressure. Serbia’s SEEPEX remained significantly discounted at €68.60/MWh, while Montenegro’s BELEN dropped further to €59.73/MWh, the lowest regional benchmark.
The regional rebound was driven primarily by a sharp deterioration in renewable generation conditions. Total SEE solar output fell by 1,012 MW day-on-day to 5,302 MW, while wind generation dropped by another 575 MW to 3,662 MW. Combined renewable losses exceeded 1.5 GW, materially tightening the intraday balance and forcing greater thermal dispatch and cross-border imports.
The decline in renewables coincided with stronger regional consumption, which rose by 559 MW to 28,246 MW, while net imports surged by 1,570 MW day-on-day to 1,193 MW. Core imports from Austria and Slovakia into the Hungarian-SEE corridor climbed by 976 MW, highlighting renewed dependence on north-to-south power flows.
One of the clearest market signals came from the widening Hungary-Germany spread, which jumped to €9.67/MWh, reflecting tightening Central European fundamentals and stronger import economics into the SEE region. The spread had traded in negative territory earlier in the week, underscoring how quickly regional market conditions have reversed as solar generation weakened.
Generation structure across the region also shifted materially. Gas-fired output increased by 471 MW to 3,109 MW, confirming that gas units again became marginal balancing assets during evening hours. Coal generation remained elevated at 4,694 MW, while hydro production stayed relatively stable at 6,824 MW, although insufficient to offset renewable declines. Nuclear generation remained flat near 3,076 MW.
Intraday price curves reveal increasingly volatile evening peaks across the region. Hungary recorded a daily maximum price of €226.8/MWh, Romania €207.1/MWh, Croatia €192.9/MWh, and Greece €166.4/MWh, with most markets peaking during hours 21–22 as solar output collapsed after sunset while demand remained elevated. Meanwhile, midday minimum prices in several markets again approached zero, with Slovenia and Greece recording near-zero or negative intraday pricing during solar-heavy hours.
This growing divergence between midday and evening pricing continues to strengthen the economic case for battery energy storage systems across SEE markets. The widening spread between near-zero solar hours and scarcity-driven evening peaks increasingly supports merchant arbitrage models, particularly in Hungary, Romania, Bulgaria and Croatia where evening balancing volatility remains structurally elevated.
Serbia continued to trade substantially below neighboring EU markets, with SEEPEX averaging only €68.60/MWh, nearly €47/MWh below HUPX. This discount reflects Serbia’s still relatively insulated pricing structure, significant domestic coal generation exposure, and weaker integration into broader EU balancing dynamics. However, the discount also increasingly highlights long-term investment pressure surrounding Serbian generation modernization, flexibility assets, and CBAM-linked electricity market evolution.
Cross-border commercial flows showed continued structural export orientation from Romania toward Hungary and Serbia, while Greece remained a significant importing market. Romania exported approximately 752 MW toward Hungary on average, while Hungary exported around 472 MW toward Croatia and 857 MW toward Austria under base-load conditions. These patterns confirm the continued role of Hungary as the primary balancing and transit hub between Central Europe and Southeast Europe.
Forward markets remained comparatively stable despite the spot rally. Hungarian week-ahead contracts traded near €96.50/MWh, while June baseload forward prices stood around €103.50/MWh. EUA carbon allowances rose modestly to around €74.93/t, while Austrian CEGH gas prices eased slightly to €50.88/MWh. The limited movement in forwards suggests traders still view the current volatility primarily as weather- and renewable-driven rather than fundamentally structural.
Hydrological conditions continue to provide partial support for regional hydro systems. Danube flow levels remained near 6,757 m³/s, above historical averages, helping stabilize hydro output across Romania and the wider Balkan system. Nevertheless, hydro alone is proving insufficient to offset increasingly volatile solar and wind patterns during rapid weather transitions.
The broader regional backdrop also continues to shift toward deeper infrastructure and system transformation. Romania advanced large-scale renewable investment momentum through Hidroelectrica’s €188.5 million refurbishment agreement for the 335 MW Raul Mare Retezat hydropower plant and Rezolv Energy’s efforts to secure EBRD backing for a new 315 MW wind project in Constanta county.
In Serbia, Srbijagas expanded its state-backed gasification program in Leskovac, increasing the project value to €86.8 million excluding VAT, reinforcing the continued strategic role of gas infrastructure in Serbia’s balancing and industrial decarbonization framework.
Meanwhile, Bulgaria’s shutdown of one generating unit at coal-fired TPP Bobov Dol due to environmental violations further illustrates the growing operational pressure on aging lignite assets across Southeast Europe. Such regulatory interventions are likely to tighten regional reserve margins further over the coming years, particularly during renewable underperformance periods.
The current market structure increasingly resembles the transition phase already visible in Western European power systems: deep midday renewable price compression combined with sharp evening balancing spikes, rising dependence on flexible gas capacity, stronger north-south interconnection flows, and growing value for storage and fast-response flexibility assets. Across SEE markets, these dynamics are gradually reshaping investment economics for renewables, storage, gas balancing infrastructure, and cross-border trading strategies.