The dynamics of price spreads and forward markets in Southeast Europe (SEE) are increasingly revealing the complexities of the region’s electricity system. As of February 25, 2026, the fragmented nature of SEE forward markets continues to pose challenges, particularly with persistent basis risks among trading hubs. While spot prices indicate immediate market conditions, forward curves provide insights into expectations regarding fuel costs, carbon pricing, and regulatory stability.
Recent spot market data highlights significant price disparities across various exchanges. For instance, HUPX reported a price of 107.7 EUR/MWh, while BSP followed at 100.4 EUR/MWh. Other exchanges such as CROPEX, OPCOM, HENEX, SEEPEX, BELEN, and ALPEX displayed even lower prices ranging from 45.5 EUR/MWh to 94.1 EUR/MWh. These inconsistencies underscore the necessity for traders and utilities to manage basis spreads actively.
A key indicator of structural challenges is the HU–DE spot spread, which was recorded at 13.7 EUR/MWh. This figure illustrates a growing decoupling between the Hungarian market and the German reference hub, driven by limited cross-border capacity and differing generation mixes. In the forward market context, this situation translates into ongoing HU–DE basis risk rather than convergence.
The volatility in forward power contracts for Week 10 was evident with Hungary experiencing a sharp decline of -8.17%, contrasting with Germany’s decrease of -1.16% and Italy’s -0.48%. This sensitivity indicates how closely SEE-adjacent markets respond to changes in system balance and fuel availability. Hungarian forward prices for WK10 were noted at 95.50 EUR/MWh, with expectations for WK11 rising slightly to 99.00 EUR/MWh.
The implications of gas prices are also critical; the Austrian CEGH gas contract for March 2026 traded at 33.26 EUR/MWh. This pricing positions gas-fired generation as a marginal player during peak hours in Hungary and neighboring regions, reinforcing exposure to gas volatility rather than facilitating a transition towards renewable energy sources.
Carbon pricing remains another influential factor affecting forward spreads; EUA Dec-26 contracts increased by 2.17%, contributing to higher thermal generation costs across coal-heavy systems in SEE. On February 25, coal forward indicators (API-2) were reported at approximately 107–108, indicating that coal can no longer serve as a low-cost option for these markets.
The interplay between gas prices, coal costs, and carbon pricing generates an environment where thermal marginality is both costly and unpredictable. As a result, forward curves in Hungary, Slovenia, and Croatia maintain elevated premiums compared to Balkan markets despite any temporary price reductions due to hydro or solar output fluctuations.
The depth of forward markets varies significantly; HUPX and BSP offer liquidity for week-ahead and month-ahead products that enable utilities to hedge effectively against load fluctuations. Conversely, exchanges like SEEPEX, BELEN, and ALPEX lack sufficient liquidity in their forward markets, compelling participants to seek proxy hedges through contracts from more liquid markets like Hungary or Slovenia.
This situation creates inherent basis risks that cannot be entirely mitigated; for instance, Serbian utilities hedging via HUPX may encounter discrepancies between the spot price on SEEPEX (53.6 EUR/MWh) and Hungarian forwards (95–100 EUR/MWh). Although some cross-border flows may partially address this gap, regulatory constraints hinder full alignment.
The asymmetry in basis risk is noteworthy; while Hungarian entities hedging against Balkan markets face reduced uncertainty due to generally lower downstream prices, Balkan participants must navigate both price level risks and volume uncertainties during peak demand or low hydrology periods.
The increasing contribution from renewables adds complexity to these dynamics; on February 25 alone, wind and solar output peaked at 5,704 MW, leading to lower midday prices but heightened evening peaks. As solar energy becomes more prominent in Romania, Bulgaria, and Greece during summer months, it is expected that peak product premiums will widen further.
Bulgaria’s deployment of a battery storage system with a capacity of 124 MW / 496.2 MWh, supported by long-term revenue hedges illustrates potential stabilization benefits for cash flows; however, regional storage capabilities remain insufficient for arbitraging multi-day or seasonal price variations.
The current structure of SEE’s forward markets indicates a shift towards spread-based strategies among traders who are increasingly focusing on differentials such as HU–DE rather than absolute price movements. These differentials reflect enduring system characteristics that offer more predictability over time than transient volatility.
Sustained forward premiums exceeding 90 EUR/MWh in Hungary and Slovenia signal investment opportunities in flexible assets like gas peakers or storage solutions while maintaining pressure on new thermal capacity developments within Balkan markets where prices hover around 50–60 EUR/MWh.
This divergence has significant long-term implications: as carbon pricing tightens alongside volatile gas markets, it is likely that SEE’s forward curves will steepen rather than flatten over time. Markets directly linked to EU hubs are expected to respond more swiftly to risks compared to peripheral areas which may experience delayed adjustments followed by rapid repricing when constraints become apparent.
The data from late February thus emphasizes that SEE’s forward markets function primarily as mechanisms for risk allocation rather than convergence tools; they encapsulate structural market differences while shaping expectations around fuel costs and carbon pricing dynamics within the region’s power landscape.
