SEE power prices rise on 21 April as demand pressure tightens balances and deepens cross-border dependence

South-East Europe’s power market moved higher on 21 April, driven less by supply disruption than by a sharp jump in demand that outpaced generation. The resulting deficit pushed systems deeper into imports, tightened regional spreads, and reinforced SEE’s role as a balancing corridor between Central Europe and the Mediterranean.

Day-ahead prices firm across most markets

Day-ahead prices rose in a broad upward band across most countries. Hungary reached 122.6 €/MWh, Romania was at 117.4 €/MWh, and Serbia traded at 113.8 €/MWh, while Croatia and Bulgaria were around 109–110 €/MWh. Greece remained structurally discounted at 83.1 €/MWh, keeping a persistent south-north spread of nearly 40 €/MWh that continues to anchor physical flows toward higher-priced Central European markets.

Demand surge widens the import-covered gap

The price increase tracked a widening imbalance: total consumption across SEE and the Hungarian system rose to 30,658 MW, up 2,003 MW day-on-day. Generation increased more slowly to 27,848 MW, leaving a larger deficit covered by imports. Net imports rose to 1,412 MW—up 604 MW—signaling that external supply again played a marginal role in shaping price formation.

Central European pricing signals pull flows deeper into SEE

A key driver behind the tighter conditions was the widening Hungary–Germany price spread to around 40 €/MWh (up approximately 17 €/MWh). That differential supported stronger inflows into Hungary from Austria and Slovakia, with core imports increasing by more than 600 MW. The pattern underscores how price signals originating further upstream in Europe continue to influence marginal pricing across the broader region.

Renewables shift but do not remove scarcity pressure

Operationally, the generation mix added volatility rather than relief. Wind output increased by 796 MW but was offset by a decline in solar generation of 264 MW, pointing to intraday variability instead of structural weakness. Hydro generation rose by 457 MW and gas-fired output increased by 179 MW—indicating thermal units were needed to stabilize the system as renewable profiles changed. Coal output edged slightly lower, maintaining a declining but still relevant balancing role.

Even with strong wind production, the system remained sensitive to solar fluctuations, particularly during peak hours when price spikes persisted. Peak prices in Hungary approached 270 €/MWh, while Serbia recorded highs near 165 €/MWh. Off-peak prices stayed elevated in the 120–140 €/MWh range, suggesting sustained pressure rather than isolated events.

Cross-border flows confirm SEE’s transit-and-balancing function

Cross-border trading further illustrated how SEE is increasingly defined by interconnections rather than purely national balances. Flows from Romania to Hungary were recorded at roughly 900 MW. Exports from Bulgaria into Serbia continued alongside exports from Hungary southward. At the same time, activity toward Italy and Greece remained active, reflecting ongoing arbitrage between higher-priced Central Europe and structurally lower-priced southern markets.

The market implication is that electricity is being routed dynamically across borders to capture spreads—turning SEE into an effective price transmission zone between major European hubs. With cross-border capacity expansion particularly along the north-south axis reinforcing this behavior, control over transmission corridors becomes central to how much influence the region can exert on wider pricing outcomes.

Fuel costs offer limited offset as carbon rises

Fuel and carbon markets provided only partial relief for wholesale pricing. Gas prices at Austria’s CEGH hub were broadly stable around 42 €/MWh, while coal continued a gradual decline. However, EU ETS December 2026 contracts moved higher, lifting carbon allowances and reinforcing a structural cost floor for thermal generation.

This divergence—easing fuel input costs alongside rising carbon—helps explain why electricity prices remained elevated even as marginal fuel economics improved for generators that rely on gas or coal for stability.

Outlook: volatility likely within an elevated band

Looking ahead, forecasts point to continued volatility within a broadly elevated range rather than a sharp reset lower. Weather signals suggest only modest cooling, implying demand may stabilize but not fall quickly. Wind output is expected to remain variable; solar generation should recover during daytime hours, which could ease peak pressure without eliminating it.

Prices are therefore likely to stay within a roughly 100–130 €/MWh corridor, with periodic spikes above 150 €/MWh during high-demand intervals. Intraday volatility should persist as renewable intermittency interacts with cross-border flow adjustments.

For market participants, the environment continues to favor cross-border trading strategies and intraday positioning as spreads between Hungary and neighboring markets remain tradable and balancing needs grow under tighter conditions. More broadly, SEE is increasingly acting as an integral part of Europe’s power system—where demand shocks, renewable variability and cross-border flows interact in real time to shape prices not only locally but across interconnected hubs.