The power markets in Southeast Europe (SEE) experienced a notable decline on 16 April 2026, reflecting a broader trend of cooling prices across the region. This shift followed a spike in day-ahead prices during the previous session, as net system imports plummeted and solar energy output significantly decreased from elevated levels. The regional pricing landscape showed Hungary leading at €127.65/MWh, followed by Romania at €121.10/MWh, and Serbia at €115.16/MWh. Other markets included Croatia at €115.07/MWh, Slovenia at €113.75/MWh, North Macedonia at €113.84/MWh, Montenegro at €109.16/MWh, Bulgaria at €104.53/MWh, and Albania at €97.89/MWh, with Greece remaining the lowest at €91.60/MWh. Notably, Albania and Greece recorded the most substantial day-on-day price drops of €48.6/MWh and €34.3/MWh, respectively.
Underlying these price movements is a significant shift in regional physical balance. Total consumption across SEE decreased to an average of 30,184 MW, down 282 MW from the previous day. In contrast, total generation saw a sharper decline to 29,052 MW, falling by 1,048 MW. The most striking change was in net imports, which dropped from 1,414 MW on 15 April to just 49 MW on 16 April—a contraction of 1,462 MW. This reduction in import dependency contributed to the observed price declines without leading to a complete market collapse.
The generation mix for the day reflected typical spring shoulder-market dynamics, with hydro generation increasing to 7,434 MW while coal, gas, and wind outputs registered at 4,659 MW, 4,124 MW, and 2,247 MW respectively. Solar power output fell to 3,487 MW—a decrease of 812 MW day-on-day—while nuclear output remained stable at approximately 5,825 MW. This indicates that the market was not solely influenced by a surge in renewable energy; rather, it benefitted from consistent hydro and thermal production while losing some support from solar energy.
Despite the overall decline in prices, Hungary maintained its position as the pricing leader within the region. The HU-DE day-ahead spread narrowed to €16.96/MWh—down by €6.2/MWh from the previous day—yet remained sufficient to keep Hungary atop the regional pricing hierarchy. Forward market structures suggest that Hungary continues to exhibit relative firmness compared to Germany with projected HU-DE spreads of €18.5/MWh for Week 17 and €20/MWh for Cal-26.
Intraday trading patterns revealed critical insights into market behavior during peak hours. Across various exchanges including HUPX and OPCOM, evening peaks were identified as stress points where most markets recorded their highest prices between hours 20–22. For instance, Hungary reached a maximum of €278.0/MWh while Romania peaked at €220.4/MWh and Serbia at €171.0/MWh during this period.
In the western Balkans specifically, Serbia and Montenegro remained closely aligned with core continental trends rather than tracking the softer Greek market dynamics. Prices for SEEPEX and BELEN were both lower compared to previous days but did not deviate significantly from regional averages. Serbia’s daily profile illustrated a pronounced evening ramp-up alongside a robust off-peak structure indicative of sustained thermal support.
Cross-border flow data corroborated these observations; Romania emerged as the strongest net exporter with an average of approximately 1,041 MW while Greece and Bulgaria also demonstrated export capabilities around similar figures. Conversely, Croatia (-616 MW), Serbia (-338 MW), and Hungary (-798 MW) were net importers on this day.
The broader commodity backdrop was slightly softer as well; CEGH gas prices fell to €43.93/MWh while coal forwards decreased to $103/t for May-26 delivery. These commodity shifts did not fully account for the power market corrections but contributed to an overall easing tone.
In summary, while prices on 16 April represented a correction following previous highs rather than a fundamental shift in market dynamics, they highlighted ongoing concerns regarding evening scarcity and continued reliance on thermal generation amidst fluctuating renewable outputs. Key factors moving forward will include potential rebounds in solar generation after recent declines and whether hydro resources can maintain their compensatory role in balancing demand.
