On April 17, 2026, the South East European day-ahead power markets witnessed a notable decline in prices, reflecting a shift towards a more balanced supply-demand dynamic driven by increased renewable energy generation and reduced reliance on imports. The Hungarian benchmark on HUPX settled at €99.37/MWh, down €28.3/MWh from the previous day, while Romania’s OPCOM closely followed at €99.29/MWh. Slovenia’s BSP and Croatia’s CROPEX recorded prices of €99.80/MWh and €99.33/MWh, respectively, indicating a strong coupling among Central-Eastern European markets around the €100/MWh mark.
In contrast, southern markets exhibited greater price divergence due to enhanced solar energy contributions. Serbia’s SEEPEX fell to €85.83/MWh, down €29.3/MWh; Bulgaria’s IBEX dropped to €85.97/MWh, a decrease of €18.6/MWh; and Albania’s ALPEX reached €84.44/MWh, down by €13.4/MWh. Greece emerged as the lowest-priced market at €77.40/MWh, benefiting from significant solar-induced price compression during midday hours. Montenegro remained an outlier with a clearing price of €100.68/MWh, maintaining a premium over its regional counterparts despite the overall bearish trend.
The observed price correction can be attributed to a substantial improvement in the regional generation-consumption balance. Total electricity generation surged to 29,714 MW while consumption decreased to 29,542 MW, resulting in a net export position of 585 MW—an impressive turnaround from the previous day’s import dependency.
Renewable energy sources played a crucial role in this transformation. Wind generation increased significantly by 1,261 MW to reach 3,528 MW, while solar output rose by 399 MW to 4,223 MW, effectively displacing higher-cost thermal generation sources. In contrast, gas-fired generation saw a sharp decline of 818 MW to 3,305 MW, illustrating the merit-order effect of renewables on pricing dynamics. Coal generation slightly decreased to 4,411 MW, while hydropower remained stable at 7,146 MW and nuclear output held steady at 5,815 MW.
Despite the downward trend in spot prices, forward market indicators provided limited bearish signals. European carbon allowances increased to €74.69/t and Austrian hub gas prices rose marginally to €44.06/MWh. Forward power contracts in Hungary also showed strength with Week 17 priced at €103.50/MWh and Week 18 at €96.50/MWh—indicative of a divergence between immediate physical market conditions and future expectations.
Cross-border trading dynamics further contributed to the softer pricing environment as the Hungary-Germany spread narrowed significantly to -€5.3/MWh—down over €22/MWh from the previous day—diminishing arbitrage opportunities for imports from central European markets. Simultaneously, imports from Austria and Slovakia into the HU+SEE region decreased by 747 MW, leading total core inflows down to 696 MW while overall regional net imports improved by 618 MW.
Intraday pricing trends reflected typical spring conditions without extreme stress indicators; midday prices fell into low double-digit ranges with Hungary recording minimums of €8.7/MWh and Romania at €8.6/MWh—Greece even approached near-zero levels during peak solar generation hours. However, peak-hour prices remained elevated but contained within the range of €150/MWh to €165/MWh.
The structural flow patterns across the region highlighted ongoing asymmetries: Hungary and Romania emerged as key redistribution hubs exporting electricity toward Croatia and into the Western Balkans while Serbia and Bosnia and Herzegovina continued to rely on imports for their needs. Greece and Albania displayed typical volatility linked to solar generation fluctuations and interconnection limitations.
This trading session signals that the SEE market has entered a renewables-driven phase characterized by rapid price compression due to incremental increases in wind and solar output across the curve. The convergence around €99–100/MWh suggests robust coupling under balanced conditions; however, sharper declines in Greece, Bulgaria, and Serbia indicate localized oversupply during daylight hours.
Looking ahead, the sustainability of this softer pricing regime will hinge on renewable output stability alongside demand trends over the weekend. With forecasted consumption expected around 29.5 GW amid stable temperatures, continued strength in wind and solar could exert further downward pressure on prices—especially in southern markets. Conversely, any reduction in renewable generation could quickly tighten evening supply conditions and elevate peak-hour prices back toward the embedded range of €120–160/MWh seen earlier in intraday curves.
