Electricity markets across South East Europe and Central Europe displayed a fragmented trajectory on 15 April 2026, as declining prices in core markets contrasted with sharp increases in the southern Balkans. The divergence reflected localized supply constraints, shifting renewable output, and heightened cross-border flows, reinforcing the structural complexity of the interconnected European power system.
Day-ahead prices softened across most coupled markets. Hungary’s HUPX settled at 140.67 €/MWh, down 3.5 €/MWh from the previous session, while Romania’s OPCOM fell to 134.98 €/MWh, a decline of 4.8 €/MWh. Bulgaria’s IBEX dropped to 125.42 €/MWh, Greece’s HENEX to 125.87 €/MWh, Slovenia’s BSP to 128.85 €/MWh, and Croatia’s CROPEX to 130.03 €/MWh. Germany’s benchmark price stood lower at 117.53 €/MWh, while Italy remained comparatively elevated at 140.19 €/MWh, highlighting persistent price gradients across the continent.
In contrast, the southern and less tightly coupled markets recorded significant increases. Serbia’s SEEPEX surged to 132.99 €/MWh, North Macedonia’s MEMO rose to 127.22 €/MWh, Montenegro’s BELEN reached 122.16 €/MWh, and Albania’s ALPEX soared to 146.50 €/MWh, the highest level in the region on the day. These movements underscore localized supply tightness and transmission constraints, which periodically decouple peripheral markets from the broader European trend.
Demand and generation dynamics
Fundamental market drivers pointed to a tightening regional balance. Electricity consumption climbed to 30,837 MW, representing an increase of 758 MW compared with the previous day. Total generation reached 29,662 MW, supported by higher thermal output and increased imports, confirming the system’s reliance on flexible and dispatchable capacity during periods of fluctuating renewable production.
Net imports rose sharply to 1,534 MW, up 1,116 MW day on day, while core imports reached 2,782 MW, highlighting stronger reliance on cross-border electricity flows. The widening HU–DE spread of 23.14 €/MWh further emphasized Hungary’s relative tightness compared with Germany, maintaining incentives for imports from Western Europe.
Thermal generation played a decisive role in balancing the system. Gas-fired output climbed to 4,103 MW, increasing by 992 MW, while coal-fired generation rose to 4,590 MW, up 398 MW. Nuclear production remained stable at 5,839 MW, and hydro generation provided significant flexibility at 7,193 MW, accounting for the largest share of the regional energy mix.
The overall generation structure reflected a balanced but thermally supported system, with hydro accounting for approximately 26%, nuclear 21%, coal 16%, gas 15%, solar 14%, and wind 7% of output.
Renewable output and weather influence
Renewable generation trends were mixed. Solar output declined to 3,956 MW, down 162 MW from the previous day, while wind production stood at 2,061 MW, registering only marginal growth. Forecast data also indicated weaker solar and wind generation across parts of the region, contributing to localized price increases and greater reliance on thermal capacity.
Temperatures across SEE and Hungary ranged between 13°C and 16°C, slightly above seasonal norms, supporting moderate demand levels. The interplay between warming conditions and variable renewable output played a critical role in shaping intraday price volatility.
Cross-border flows and market coupling
Interconnection dynamics continued to influence price formation. The SEE region maintained strong import activity from Central Europe, with Austria and Slovakia supplying electricity into Hungary and neighboring markets. Elevated price spreads and congestion risks contributed to market segmentation, particularly in the southern Balkans, where liquidity remains comparatively limited.
Commercial flow data over the past week indicated persistent cross-border exchanges among Bulgaria, Romania, Hungary, Serbia, and Greece, highlighting the strategic importance of regional interconnectivity for system stability and price convergence.
Forward markets and commodities
Forward indicators provided a stable outlook despite day-ahead volatility. Austrian gas prices at the Central European Gas Hub stood at 46.12 €/MWh, declining by 3.2 €/MWh, while EU Emissions Allowances traded at 74.87 €/t, up 2.3 €/t.
Hungarian power forwards reflected moderate stability, with Week 17 priced at 104.50 €/MWh, Week 18 at 92.50 €/MWh, May 2026 at 93.00 €/MWh, and Calendar 2026 at 108.50 €/MWh. These levels suggest expectations of gradual normalization in the months ahead, supported by improving renewable generation and stable fuel costs.
Coal and gas forward curves trended slightly lower, reinforcing a bearish medium-term cost outlook for thermal generation. Meanwhile, carbon prices remained resilient, continuing to influence the marginal cost of fossil-fuel-based electricity production across Europe.
Intraday trends and volatility
Hourly price curves revealed pronounced evening peaks across major exchanges, driven by declining solar generation and sustained demand. On the Hungarian HUPX market, prices reached a daily maximum of 275.1 €/MWh, reflecting evening tightness and confirming the growing importance of flexibility assets such as gas-fired plants and energy storage.
Similar patterns were observed across Romania, Slovenia, and Greece, highlighting synchronized peak-demand dynamics across interconnected European markets.
The daily trading data underscores three defining themes shaping regional electricity markets. First, price divergence remains a structural feature of South East Europe, driven by varying levels of market coupling and infrastructure capacity. Second, thermal generation continues to serve as a critical balancing mechanism amid fluctuating renewable output. Third, cross-border interconnections remain essential for ensuring price convergence and system stability.
Looking ahead, improving weather conditions and increased renewable generation may exert downward pressure on prices, while continued geopolitical and fuel-market uncertainties could sustain volatility. As Europe accelerates its energy transition, SEE markets will remain highly sensitive to interconnection constraints, generation mix shifts, and regional demand fluctuations.
The trading session of 15 April 2026 ultimately highlighted a nuanced market environment: a softening trend in core European hubs contrasted with tightening conditions in the southern Balkans, reinforcing the importance of regional dynamics in shaping electricity price formation.