On April 15, 2026, the electricity markets in Southeast Europe and Central Europe exhibited a notable divergence in pricing trends. While core markets experienced a decline in prices, southern Balkan nations saw significant price increases. This contrast can be attributed to localized supply constraints, variations in renewable energy output, and intensified cross-border electricity flows, highlighting the intricate dynamics of the European power system.
Day-ahead market prices reflected this fragmentation. In Hungary, the HUPX market settled at 140.67 €/MWh, down 3.5 €/MWh from the previous day. Romania’s OPCOM followed suit, dropping to 134.98 €/MWh, a decrease of 4.8 €/MWh. Other markets also reported lower prices: Bulgaria’s IBEX at 125.42 €/MWh, Greece’s HENEX at 125.87 €/MWh, Slovenia’s BSP at 128.85 €/MWh, and Croatia’s CROPEX at 130.03 €/MWh. Conversely, Germany’s benchmark price fell to 117.53 €/MWh, while Italy maintained a higher price point at 140.19 €/MWh.
The southern Balkan markets diverged sharply from these trends. Serbia’s SEEPEX surged to 132.99 €/MWh, North Macedonia’s MEMO increased to 127.22 €/MWh, Montenegro’s BELEN reached 122.16 €/MWh, and Albania’s ALPEX soared to an impressive 146.50 €/MWh. These price increases underscore regional supply tightness and transmission constraints that periodically isolate these markets from broader European pricing trends.
The demand and generation landscape across the region indicated tightening conditions as electricity consumption rose to 30,837 MW, up by 758 MW. Total generation was recorded at 29,662 MW, bolstered by increased thermal output and imports, illustrating the system’s dependence on flexible generation sources amidst fluctuating renewable energy production.
A sharp rise in net imports was noted, reaching 1,534 MW, an increase of 1,116 MW. Core imports peaked at 2,782 MW, underscoring a strengthened reliance on cross-border electricity flows during this period of tight supply conditions. The widening spread between Hungary and Germany of 23.14 €/MWh further emphasized Hungary’s relative market tightness.
The contribution of thermal generation was critical for balancing the overall system; gas-fired output rose to 4,103 MW, an increase of 992 MW, while coal-fired generation climbed to 4,590 MW. Nuclear power remained stable at 5,839 MW, with hydro generation providing crucial flexibility at 7,193 MW.
The mix of energy sources revealed a balanced yet thermally supported structure: hydro represented approximately 26%of output; nuclear accounted for 21%; coal made up around 16%; gas contributed 15%; solar provided 14%; and wind accounted for 7%.
Renewable energy output showed mixed results during this period.Solar generation fell to 3,956 MW —a drop of 162 MW—while wind production saw marginal growth at 2,061 MW . Forecasts indicated weaker solar and wind generation across various regions which contributed to localized price spikes and increased reliance on thermal capacity.
The weather conditions across Southeast Europe ranged between temperatures of 13°C and 16°C, slightly above seasonal averages which supported moderate demand levels throughout the region.
Cross-border trade dynamics continued to play a pivotal role in shaping regional electricity prices.The SEE region maintained robust import activities from Central Europe with Austria and Slovakia supplying power into Hungary and adjacent markets. Elevated price spreads coupled with congestion risks highlighted market segmentation issues particularly prevalent in the southern Balkans where liquidity remains constrained.
Forward market indicators suggested stability despite day-ahead volatility.Austrian gas prices settled at 46.12 €/MWh —a decline of 3.2 €/MWh—while EU Emissions Allowances traded higher at 74.87 €/t —an increase of 2.3 €/t.
In Hungary’s forward market:Week 17 was priced at 104.50 €/MWh; Week 18 at 92.50 €/MWh; May 2026 futures were set at 93.00 €/MWh; while Calendar Year 2026 stood at 108.50 €/MWh—indicating expectations for gradual normalization supported by improving renewable outputs and stable fuel costs.
The volatility observed during intraday trading sessions highlighted pronounced peaks during evening hours across major exchanges due to diminishing solar output against sustained demand levels.On the Hungarian HUPX market alone, prices peaked daily at an impressive maximum of275.1 €/MWh due to evening tightness emphasizing the growing importance of flexibility assets such as gas-fired plants and energy storage solutions.
This trading session ultimately illustrated three key themes within regional electricity markets: ongoing price divergence driven by varying levels of infrastructure capacity; thermal generation acting as a crucial balancing force amid changing renewable outputs; and the essential nature of cross-border interconnections for ensuring system stability and price convergence across Europe.
The evolving landscape suggests that improving weather conditions alongside increased renewable generation may exert downward pressure on future prices; however geopolitical uncertainties may sustain ongoing volatility within these interconnected markets moving forward.
