Hungary’s HUPX day-ahead baseload price decreased to €120.07/MWh, reflecting a €16.5/MWh drop from the previous day. Similarly, Romania’s OPCOM closed at €121.10/MWh, also down more than €16/MWh. Other markets showed similar trends, with Slovenia’s BSP falling to €110.66/MWh and Croatia’s CROPEX declining to €113.13/MWh. Montenegro’s BELEN saw a significant decrease to €100.32/MWh, while Greece maintained its position as the lowest-priced major market at €94.38/MWh, attributed to robust solar output and reduced demand pressures.
The regional power balance indicates a substantial rise in net imports into the HU+SEE system, which reached approximately 926 MW—almost 1 GW higher than the previous day. Key imports from Austria and Slovakia into Hungary and the SEE system rose to 1,140 MW, facilitated by favorable west-to-east flow dynamics as the Hungarian-German price spread exceeded €25/MWh.
Generation statistics confirm that the observed market softening was largely driven by renewables, with total SEE generation increasing by around 1.7 GW day-on-day to reach 28,069 MW. Solar output surged to 5,543 MW while hydro generation climbed to 6,542 MW. Wind power remained stable above 3.5 GW, contributing to price compression during midday hours. Additionally, coal generation rose to 4,486 MW, indicating ongoing operational activity among thermal units despite declining spot prices.
The intraday pricing structure across HUPX, BSP, OPCOM, and SEEPEX revealed significant volatility patterns; prices plummeted during midday hours characterized by high solar production before rebounding sharply during peak evening periods where prices exceeded €180-260/MWh in several markets. Serbia’s SEEPEX exhibited comparatively high minimum prices relative to its neighbors, remaining above €50/MWh for daily minimums due to limited domestic flexibility and reliance on balancing.
Cross-border flow data underscores Serbia’s crucial role as a transit hub within the region’s electricity network. Recent averages indicate strong imports from Hungary into Serbia at about 922 MW baseload and 724 MW peak. Concurrently, Romania maintained robust exports toward Hungary, reinforcing established north-south flow dynamics across Central and Southeast Europe.
Market conditions were further supported by favorable fuel pricing trends; Austrian CEGH gas for June settled around €48.23/MWh while EUA carbon prices eased towards €75/t. Coal futures also softened slightly, leading to lower marginal costs for thermal generation across the region.
The ongoing structural evolution within SEE is increasingly shaped by solar energy expansion and associated risks of midday oversupply. Initiatives such as Romania’s PPC Energie pilot project—offering free electricity during peak solar periods—demonstrate how utilities are adapting demand patterns in response to renewable generation profiles. Additionally, EVN Macedonia’s launch of a 10 MW / 20 MWh battery storage system at Probistip highlights growing investments in balancing infrastructure amid rising market volatility.
Hydrological conditions remain favorable as well; Danube flow levels are currently elevated compared to long-term averages, supporting hydroelectric production throughout the Balkan region and mitigating upward pressures on regional spot prices.
As traders navigate this evolving landscape characterized by pronounced solar-driven intraday pricing fluctuations and aggressive evening price spikes, Serbia, Romania, and Hungary are positioned as key anchors of volatility due to their unique interplay of renewable growth trajectories and interconnection dependencies within this fragmented market structure.
