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SEE day-ahead power prices slide on 2 April as imports rise and gas eases, but tight system conditions remain
Day-ahead electricity markets across Southeast Europe and Hungary corrected lower on 2 April, reversing part of the prior session’s rally as improved cross-border inflows, stronger renewable production and softer gas pricing combined to ease immediate pressure. While the move was synchronized across most trading hubs, the underlying picture still points to a structurally tight system rather than a durable shift into oversupply.
Hungary’s HUPX cleared at €135.80/MWh, down €18.5/MWh day on day. In Romania, Bulgaria and Greece—OPCOM, IBEX and HENEX respectively—the market converged around €136.58/MWh, with each falling by roughly €18–20/MWh. Slovenia’s BSP dropped to €133.91/MWh, Croatia’s CROPEX to €134.25/MWh, and Serbia’s SEEPEX printed €132.32/MWh, the steepest regional decline at €26.2/MWh.
Not all markets moved in lockstep with the same directionality at the extremes: Albania remained structurally decoupled on the downside at €110.41/MWh, while Montenegro continued to trade at a premium of €141.29/MWh, reflecting local constraints and system positioning.
Imports improve first signal for traders
The scale and simultaneity of the correction suggests a shared regional driver set rather than isolated adjustments by individual countries or exchanges. Cross-border flows were central to that shift: net imports into the broader SEE system rose sharply to 1,972 MW, up by 903 MW versus the previous day. For the Hungary-linked system specifically, core inflows climbed to 3,442 MW, an increase of 770 MW. With more external supply available, marginal thermal generation requirements eased—allowing prices to retrace from earlier elevated levels.
Renewables reduce gas burn even as coal holds steady
At the same time, generation mix improved in ways that directly affect marginal pricing dynamics in these markets. Wind output increased to 3,482 MW, up by 227 MW day on day, while solar stayed broadly stable at 3,249 MW. Hydro edged higher as well to 8,200 MW. Together, those changes reduced reliance on gas-fired plants: gas output fell to 5,416 MW, down by 437 MW</stron g from the previous day.
C oal generation remained relatively stable at 6 ,253 MW , continuing to provide baseload support.
No surplus—imports still cover a structural gap
The price drop did not translate into a surplus condition across the region. Total generation stood at 33 ,978 MW against consumption of 35 ,334 MW , leaving a structural deficit covered by imports. That dependency helps explain why corrections can be sharp when inflows improve—but also why they may not last if import availability weakens or fuel costs firm again.
Softer gas pulls down forward expectations modestly
The easing pressure extended beyond spot pricing into fuel-linked benchmarks. Austrian CEGH gas traded at €50 .76/MWh , down by €4 .5/MWh . Forward gas and power contracts softened modestly across parts of the curve as well.
In Hungary’s power forwards for Week 15 were assessed at €74 .64/MWh ; April 2026 was priced at €110 .50/MWh ; and Cal-2026 came in at €112 .50/MWh . Coal benchmarks declined too, while carbon allowances were relatively stable—pointing to gas as the main driver behind today’s downward impulse rather than emissions pricing.
Tightness shows up in forward levels—and intraday swings persist
<pEven with spot prices falling sharply, forward curves remain elevated relative to historical norms. That pattern indicates investors are still underwriting structural risk rather than assuming short-term comfort will dominate going forward.
The report also highlights ongoing geopolitical uncertainty—particularly Middle East tensions affecting global energy flows—as a factor supporting European gas pricing pressures that feed through into power markets more broadly.
A key reminder for traders is that volatility remains high within days like this one. Peak-hour prices across HUPX, BSP and OPCOM continued to exceed €170–230/MWh during evening hours, while midday values softened more noticeably due to solar generation. The widening intra-day spread reflects how renewable intermittency is layered onto a thermally constrained base—an arrangement that tends to amplify swings instead of smoothing them out.
Sensitivity varies by market position inside SEEPEX framework
Serbia’s placement within this environment appears particularly sensitive but not outside it: SEEPEX settled at €132 .32/MWh , slightly below regional averages on the day—signaling competitive positioning for that session—yet still firmly within the high-price band overall.
The exchange also recorded March trading volumes of 447 ,933 MWh , with an average base price of €94 .67/MWh . That figure was up 38% month on month , underscoring that elevated price levels persist even after daily declines.
The structural mechanics behind divergence remain intact
The regional system continues to show three defining characteristics shaping outcomes for investors looking for directional clarity:
- Import dependence: cross-border flows play a decisive role in price formation;
- Marginal role for gas: despite growing renewables capacity, gas remains central in setting marginal prices;
- Narrow interconnection capacity: congestion drives localized divergence—including Montenegro’s premium versus Albania’s discount.
A widening Hungary-Germany spread of €21 .76/MWh widens attention further toward Central Eastern Europe’s partial decoupling from Western European price dynamics due to transmission constraints and differing supply conditions.
A near-term repricing depends on whether today’s drivers hold up tomorrow
The durability of today’s correction hinges on whether key factors observed on 2 April persist. Continued strong renewable output alongside stable or improving import availability could keep prices under pressure in coming sessions.
If instead there is tightening in gas markets, weaker cross-border flows or declining wind generation, today’s relief would likely unwind quickly given how closely power pricing tracks fuel costs under these conditions.
The market therefore looks less like it has turned bearish outright—and more like it has been temporarily rebalanced within a framework defined by import coverage needs and persistent tightness—where volatility remains dominant and directional moves are driven primarily by short-term shifts in imports and fuel pricing rather than fundamental oversupply.
