Wind slump lifts day-ahead power prices across Southeast Europe and Hungary

Power prices across Southeast Europe and Hungary rebounded sharply on Monday delivery, reversing a softer weekend trend as wind generation fell and the system shifted toward more expensive thermal output and imported electricity. The move mattered for traders and utilities because it showed how quickly marginal costs can reset when renewable supply tightens—especially in markets where interconnection flows route higher-cost power into the region.

Hungary sets the pricing anchor as thermal and import dependence rise

Hungary’s HUPX cleared at €120.45/MWh, leading the regional rally and establishing the pricing reference point for Central and Southeast Europe. Prices followed across interconnected markets: Serbia’s SEEPEX rose to €109.08/MWh, Croatia’s CROPEX to €106.06/MWh, Slovenia’s BSP to €105.12/MWh, and Romania’s OPCOM to €103.52/MWh.

Southern markets remained structurally discounted even during the broad-based increase, with Greece at €83.41/MWh, Montenegro at €88.28/MWh, and Albania at €78.83/MWh. The largest day-on-day increases were concentrated in the western Balkans—Serbia (+€44.4/MWh), Hungary (+€36.6/MWh), and Romania (+€31.1/MWh)—signaling coordinated repricing driven by supply-side tightening rather than demand growth.

Wind contraction drives a faster generation-mix rebalancing

The fundamental trigger was a sharp contraction in renewable output led by wind. Total regional generation fell to 27,590 MW, down 966 MW day on day, while consumption was around 25,487 MW—leaving the system reliant on imports to balance supply.

Wind output dropped to 1,510 MW, down 2,785 MW versus the previous day, removing a key low-cost layer of generation. Solar increased modestly to 4,641 MW but was not enough to offset the wind deficit outside daylight hours.

In response, thermal units ramped up clearly: gas-fired generation rose to 2,702 MW (+296 MW) and coal increased to 4,608 MW (+63 MW). Nuclear output stayed stable at 5,794 MW, while hydro contributed 5,866 MW (slightly lower day on day due to hydrological variability). Other generation sources also rose to 2,469 MW, indicating additional balancing actions within the system.

Higher-cost imports transmit through Hungary; demand stays soft

This production shift lifted marginal costs across the region because higher-cost thermal units replaced lost renewable output. The effect was amplified by stronger import dependence: net regional imports reached 1,185 MW and core inflows rose to 2,604 MW (from Austria/Slovakia into Hungary and further into Southeast Europe).

At the same time, Hungary pulled more expensive power from the Central European core. The Hungary–Germany spread widened to around €22–23/MWh, helping transmit higher-cost electricity into Southeast Europe and reinforcing the upward price trajectory.

Despite the price surge, demand fundamentals were relatively soft: regional consumption declined by 1,520 MW day on day. That confirmed that the rally was driven almost entirely by supply-side tightening rather than load expansion.

Volatile intraday patterns show evening ramp risk

Intraday profiles followed a typical spring shape but with elevated volatility. Midday hours eased into the €30–40/MWh range in several markets as solar output supported supply; evening hours then saw sharp spikes as solar faded and thermal generation set marginal prices.

Peak prices reached above €270/MWh in Hungary and €150–175/MWh across SEE markets during the H20–H21 window. Spikes clustered around this period underscored how structural evening ramp dynamics are becoming increasingly important for market outcomes.

Regional spreads stayed divergent despite the broad rally: Hungary traded at a premium versus Serbia (about €11/MWh lower), while Croatia and Slovenia were roughly €14–15/MWh lower than Hungary. Southern markets remained discounted by more than €35/MWh—reflecting interconnection constraints and localized balances that limit full convergence.

Spot strength contrasts with softer forward pricing

Cross-border flows reinforced tightening conditions: Southeast Europe remained a net importer with increased inflows from Austria and Slovakia into Hungary that continued onward into the region. This pattern again highlighted Hungary’s role as both a transmission hub and a key pricing node through which higher-cost power enters.

Forward markets did not fully mirror spot strength. Near-term baseload contracts softened slightly; Week 17–18 and May-26 products traded in the €90–100/MWh range, suggesting participants viewed Monday’s spike as likely short-lived rather than a lasting structural change.

Gas prices were broadly stable around €42–47/MWh; carbon allowances hovered near €77/t; coal forwards edged lower. The divergence between spot and forward curves pointed toward a weather-driven event rather than an enduring shift in fundamentals.

Flexibility becomes more valuable when wind is volatile

For market participants, Monday’s session underlined the value of flexibility—particularly assets able to capture evening peaks such as hydro and gas-fired generation—while flat exposure or unhedged retail positions faced elevated peak-hour risk during periods when wind output collapses.

The broader implication for Southeast European power markets is that price formation increasingly reflects an interaction between renewable intermittency, thermal back-up costs, and cross-border import dependency—with Hungary acting as a central transmission and pricing hub. With wind expected to remain volatile in coming days, similar dynamics are likely: softer midday pricing tied to solar support earlier in the day; aggressive evening ramps when wind weakens; and continued sensitivity to flows from Central Europe into Southeast Europe.