Wind-led easing cuts spot power prices in SEE and Hungary, but the southeast premium holds

Day-ahead electricity prices across South-East Europe and Hungary saw a sharp retreat on 3 April, but the move did not erase the region’s deeper pricing fault line. While core-linked hubs softened quickly, southeastern markets held higher levels—an outcome that points less to demand collapse than to how transmission access, imports and local supply-demand tightness continue to shape settlement.

Spot correction meets a stubborn regional split

Hungary’s HUPX front-month day-ahead contract settled at €108.30/MWh, down €27.5/MWh from the previous session—one of the steepest single-day declines in recent weeks. The western SEE perimeter moved similarly: Slovenia cleared at €104.99/MWh and Croatia at €108.90/MWh, with both markets dropping by more than €25/MWh.

In contrast, the eastern complex remained structurally tight. Romania, Bulgaria and Greece all cleared at €129.62/MWh, while Serbia’s SEEPEX settled at €122.72/MWh. Together, those levels preserved a €14–21/MWh premium over Hungary. Montenegro and North Macedonia also stayed firm above the Hungarian benchmark at €116.23/MWh and €116.17/MWh, respectively.

This divergence reinforces that SEE is not trading as one fully integrated block: pricing continues to fragment along transmission constraints, differing import dependency profiles, and localized balances between supply and demand.

Milder weather and wind change the marginal unit picture

The system dynamics behind the sell-off look consistent with a temporary wind-led softening rather than a structural demand break. Regional consumption fell to 34,217 MW, down 1,341 MW, reflecting milder temperatures across the broader SEE zone.

Total generation eased only modestly to 33,354 MW, but composition shifted decisively. Gas-fired output dropped sharply to 4,211 MW, down 1,040 MW, while wind generation surged to 5,018 MW, up 522 MW. Hydro output improved to 8,398 MW, further reducing pressure on marginal-cost pricing. Solar slipped to 2,567 MW, suggesting intraday solar cannibalisation was not the primary driver of the day-ahead price move.

The generation mix illustrates why gas lost influence on clearing prices: hydro represented roughly 24% of supply (coal <b18%, gas <b12%, wind <b15%) alongside nuclear at about <b17%. Imports contributed around <b6%. With thermal burn reduced—especially gas—the market had room for spot retracement even as parts of the region stayed tight.

Imports rise as traders look past oversupply fears

A key reason southeastern prices resisted convergence is that the region remains import-reliant even during bearish sessions. Net imports increased to , up by . Flows from the core direction (Austria and Slovakia into Hungary and Slovenia) rose to , an increase of .

This matters for trading because it reframes what drove lower prices: it was not an oversupply within SEE itself so much as improved access to imported power combined with temporarily reduced thermal requirements. The persistence of a southeastern premium aligns with markets that remain more dependent on imports—and less directly connected to lower-cost core supply.

Tight forward signals keep elevated pricing expectations intact

The spot drop did not translate into an immediate repricing of longer-dated risk premia. On cross-border spreads, the market showed continued congestion-related differentiation: the <HU-DE spread widened to €23.67/MWh. That indicates Germany remained significantly cheaper while Hungary continued pricing in transmission limits and regional balancing costs.

Intraday volatility also highlighted how quickly conditions can swing under renewables influence: Hungary recorded a minimum hourly price of just <€3.0/MWh