On April 17, 2026, South East European day-ahead power markets experienced a notable drop in prices, reflecting a significant shift in the regional energy landscape. The decline was attributed to heightened renewable energy generation and a decrease in reliance on imports, leading to improved supply-demand dynamics across the region.
The Hungarian day-ahead benchmark on HUPX recorded a price of €99.37/MWh, representing a sharp €28.3/MWh decrease from the previous day. Romania’s OPCOM followed closely with a price of €99.29/MWh. Slovenia’s BSP settled at €99.80/MWh, while Croatia’s CROPEX cleared at €99.33/MWh, indicating a closely aligned price cluster around the €100/MWh mark.
In contrast, southern markets showed more pronounced price variations due to increased solar energy contributions. Serbia’s SEEPEX fell to €85.83/MWh (down by €29.3/MWh), Bulgaria’s IBEX dropped to €85.97/MWh (down by €18.6/MWh), and Albania’s ALPEX reached €84.44/MWh (down by €13.4/MWh). Greece maintained the lowest market price at €77.40/MWh, driven by significant midday solar generation effects, while Montenegro stood out with a higher clearing price of €100.68/MWh.
This downward trend in pricing was primarily fueled by an enhanced regional supply-demand balance, with total generation rising to 29,714 MW and consumption falling to 29,542 MW, resulting in a net export position of 585 MW—an impressive turnaround from the previous day’s import-heavy structure.
Renewable energy sources played a crucial role in this transformation; wind generation surged by 1,261 MW to reach 3,528 MW, while solar output increased by 399 MW to 4,223 MW. This growth effectively displaced higher-cost thermal generation methods. Conversely, gas-fired output declined significantly by 818 MW to 3,305 MW due to merit-order impacts, while coal generation slightly decreased to 4,411 MW. Hydropower remained stable at 7,146 MW despite minor reductions day on day, and nuclear power output held steady at 5,815 MW.
Despite the spot market sell-off, forward contracts and fuel prices did not exhibit significant bearish trends. European carbon allowances rose to €74.69/t and Austrian hub gas prices edged up slightly to €44.06/MWh. Hungarian forward power contracts strengthened as well: Week 17 reached €103.50/MWh; Week 18 settled at €96.50/MWh; and Cal-26 hit €110.00/MWh—indicating a disconnect between current physical market conditions and future expectations.
Cross-border trading dynamics contributed further to the softer pricing environment; the Hungary-Germany spread narrowed sharply to -€5.3/MWh—a drop of over €22/MWh from the previous day—diminishing incentives for imports from central European markets. Additionally, imports from Austria and Slovakia into the HU+SEE region decreased by 747 MW overall core inflows fell to 696 MW while total regional net imports improved by 618 MW.
Intraday price fluctuations reflected typical spring conditions without extreme stress indicators; midday prices dipped towards low double-digit levels with recorded minimums of €8.7/MWh in Hungary and €8.6/MWh in Romania alongside near-zero levels in Greece during peak hours prices remained elevated but contained within ranges of approximately €150–165/MWh.
The structural dynamics within regional flows highlighted asymmetries: Hungary and Romania emerged as key redistribution hubs exporting electricity towards Croatia and into the Western Balkans while Serbia and Bosnia and Herzegovina continued their import-dependent status with Greece and Albania experiencing southbound volatility linked to solar production variations.
The recent trading session indicates that the SEE market has entered a renewables-driven soft phase characterized by rapid price compression due to incremental increases in wind and solar generation outputs across various markets. The convergence around the €99–100/MWh range suggests strong coupling under balanced conditions while localized oversupply issues emerged particularly during daylight hours in Greece Bulgaria and Serbia.
Looking ahead market participants should closely monitor renewable output stability alongside demand trends over the weekend as forecasted consumption remains around 29.5 GW with stable temperatures anticipated Continued strength in wind and solar resources may exert downward pressure particularly on southern markets however any declines in renewable generation could quickly lead to tighter evening conditions pushing peak-hour prices back toward ranges of €120–160/MWh embedded within intraday curves.
