Price spreads and forward markets provide the clearest window into how South-East Europe’s electricity system internalizes risk over time. While spot prices reveal immediate system stress, forward curves expose expectations around fuel costs, carbon pricing, cross-border availability and regulatory stability. The data from 25 February 2026 confirms that SEE forward markets remain fragmented, with persistent basis risk between hubs and limited depth outside Central European-linked exchanges .
On the spot side, the dispersion was already pronounced, with HUPX at 107.7 EUR/MWh, BSP at 100.4 EUR/MWh, CROPEX at 94.1 EUR/MWh, and a second pricing tier comprising OPCOM at 59.0 EUR/MWh, HENEX at 54.5 EUR/MWh, SEEPEX at 53.6 EUR/MWh, BELEN at 54.5 EUR/MWh, and ALPEX at 45.5 EUR/MWh . Forward markets do not eliminate these gaps; instead, they formalize them through basis spreads that traders and utilities must actively manage.
The most visible structural indicator is the relationship between Hungary and Germany. On 25 February, the HU–DE spot spread stood at 13.7 EUR/MWh, signaling continued decoupling between the Hungarian market and the German reference hub . This spread is not an anomaly but a reflection of constrained cross-border capacity, divergent generation mixes and differing exposure to marginal thermal pricing. In forward space, this manifests as persistent HU–DE basis risk rather than convergence.
Forward power contracts for Week 10 reflected this stress. Hungarian Week 10 prices declined sharply, with Hungary posting a -8.17% weekly move, compared to -1.16% in Germany and -0.48% in Italy . The magnitude of Hungary’s move illustrates how SEE-adjacent markets remain more sensitive to marginal changes in system balance, fuel availability and imports. Forward curves in Hungary absorb not only expected fuel costs but also congestion risk and regulatory uncertainty.
Hungarian forward prices stood at 95.50 EUR/MWh for WK10 and 99.00 EUR/MWh for WK11, with Mar-26 trading around 91.50 EUR/MWh and Cal-26 near 95.00 EUR/MWh . These levels imply expectations of some normalization relative to spot peaks, but not a return to the lower pricing observed in Balkan markets. Instead, they embed a sustained premium reflecting gas-linked marginal pricing and cross-border dependency.
Gas forwards reinforce this interpretation. The Austrian CEGH gas contract for Mar-26 traded at 33.26 EUR/MWh, while Q2-26 stood at 33.00 EUR/MWh . At these levels, gas-fired generation in Hungary and neighboring markets remains firmly in the marginal stack during peak hours. The forward power curve therefore prices in continued exposure to gas volatility rather than a rapid shift toward hydro- or renewable-dominated clearing.
Carbon pricing further shapes forward spreads. EUA Dec-26 contracts rose by 2.17%, reinforcing the upward pressure on thermal generation costs . For coal-heavy systems in the region, this carbon component materially widens dark spreads and raises forward power prices even when coal fuel costs stabilize. On 25 February, coal forward indicators (API-2) hovered around 107–108 in equivalent terms, underscoring that coal is no longer a low-cost anchor for SEE markets .
The interaction between gas, coal and carbon creates a forward pricing environment in which thermal marginality is expensive and volatile. As a result, forward curves in Hungary, Slovenia and Croatia price in sustained premiums relative to Balkan markets, even when spot prices temporarily compress due to hydro or solar output. This explains why forward convergence lags spot convergence: traders price structural risk rather than daily hydrology.
Forward market depth remains uneven. HUPX and BSP support week-ahead, month-ahead and calendar products with reasonable liquidity, allowing utilities to hedge load and generation exposure. In contrast, SEEPEX, BELEN and ALPEX lack meaningful forward liquidity, forcing market participants to rely on proxy hedges through Hungarian or Slovenian contracts. This creates embedded basis risk that cannot be fully neutralized.
For example, a Serbian utility hedging forward exposure via HUPX faces a structural disconnect between the 53.6 EUR/MWh spot reality on SEEPEX and the 95–100 EUR/MWh forward levels in Hungary . While cross-border flows partially arbitrage this gap, congestion and regulatory barriers prevent full alignment. The hedge therefore covers price direction but not absolute level, leaving residual exposure.
This basis risk is not symmetric. Hungarian participants hedging against Balkan markets face less uncertainty, as downstream markets generally clear at discounts. Balkan participants hedging upstream face both price level risk and volume risk, particularly during peak demand or low hydrology. Forward markets, in this sense, reinforce the structural hierarchy of SEE trading rather than flattening it.
Renewables add further nuance to forward spreads. On 25 February, wind and solar output totaled 5,704 MW, depressing midday prices but amplifying evening peaks . Forward curves increasingly reflect this intraday shape, with peak products carrying higher premiums relative to baseload. As solar penetration increases in Romania, Bulgaria and Greece, forward peak spreads are likely to widen further, especially in summer months.
Storage is beginning to influence forward expectations but has not yet transformed them. Bulgaria’s 124 MW / 496.2 MWh battery system, supported by a long-term revenue hedge, demonstrates how storage can stabilize cash flows . However, at regional scale, storage volumes remain insufficient to arbitrage multi-day or seasonal spreads. Forward curves therefore continue to price scarcity during peak hours and winter periods.
The structure of SEE forward markets suggests that hedging behavior is shifting from outright price bets to spread-based strategies. Traders increasingly focus on HU–DE, HU–BSP and HU–CROPEX differentials, rather than absolute price direction. These spreads reflect durable system characteristics rather than transient volatility, making them more predictable over time.
From a system perspective, forward prices also send investment signals. Sustained forward premiums above 90 EUR/MWh in Hungary and Slovenia support investment in flexible assets such as gas peakers, storage and demand response. In contrast, forward prices in the 50–60 EUR/MWh range in Balkan markets limit the bankability of new thermal capacity and reinforce reliance on hydro and imports.
This divergence carries long-term implications. As carbon pricing tightens and gas markets remain volatile, forward curves in SEE are likely to steepen rather than flatten. Markets with direct exposure to EU hubs will price risk earlier and higher, while peripheral markets may experience delayed adjustment followed by abrupt repricing when constraints bind.
The data from 25 February therefore illustrates that forward markets in SEE are not mechanisms of convergence but instruments of risk allocation. They codify structural differences between markets, transmit expectations about fuel and carbon costs, and shape hedging behavior accordingly. In doing so, they preserve a layered regional structure even as physical integration deepens.
Understanding these forward dynamics is essential for participants navigating SEE power markets. Spot prices may fluctuate daily, but forward spreads reveal the deeper architecture of risk and dependency. As long as basis risk remains unresolved through deeper coupling and liquidity expansion, forward markets will continue to reflect — and reinforce — the structural asymmetries embedded in South-East Europe’s power system.
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