The electricity price structure observed on 27 February 2026 cannot be understood without examining the underlying fuel markets and generation economics that determine marginal production costs. Across Central and Southeast Europe, electricity prices remain closely tied to the relative costs of coal, gas and carbon emissions allowances.
Fuel forward markets provide the foundation for this analysis. Austrian natural gas traded near €33.19/MWh, while coal futures at the API2 benchmark hovered around $106 per tonne. At the same time, EU carbon allowances traded near €70.97 per tonne, reflecting continued tightening of emissions regulations within the European Union.
When these fuel costs are incorporated into generation economics, a clear marginal cost hierarchy emerges. Coal plants in Southeast Europe typically operate with efficiencies that produce electricity at marginal costs between €70 and €85/MWh, depending on carbon intensity and fuel quality. Gas-fired plants, by contrast, often require electricity prices above €90/MWh to operate profitably at current gas and carbon prices.
This relationship explains why coal plants continue to set marginal electricity prices in many Southeast European markets. Although the European Union has gradually increased carbon prices to discourage coal generation, the current carbon price level is not yet high enough to fully displace coal in regions where lignite remains abundant and inexpensive.
Hydropower plays a unique role within the regional generation stack. With over 11.5 GW of hydro generation operating across the region, water availability can dramatically alter electricity prices. During periods of strong river flows, hydropower plants produce large volumes of low-cost electricity that suppress wholesale prices. Conversely, during drought conditions hydro output declines and thermal plants must operate more frequently, pushing prices upward.
The Danube basin is particularly important in this context. Hydropower facilities along the Danube and its tributaries represent a major portion of Southeast Europe’s renewable generation capacity. Changes in river flows therefore have system-wide effects on electricity prices.
Renewable energy sources such as solar and wind are also becoming increasingly influential. Solar generation reached approximately 4,018 MW during the analyzed period, while wind output totaled 2,726 MW. Although these figures remain smaller than hydro or coal generation, their variability introduces significant short-term price fluctuations.
During midday hours, solar generation floods the grid with electricity, driving prices downward. As the sun sets and solar output declines, thermal plants must ramp up quickly to meet demand, causing prices to rise sharply. This pattern has become increasingly common across European electricity markets and is expected to intensify as solar capacity continues to expand.
The interaction between renewable generation and fossil fuel marginal costs creates complex price dynamics. When renewable output is high, electricity prices fall toward zero regardless of fuel costs. When renewable output declines, however, fossil fuel plants return to the top of the generation stack and determine electricity prices.
Forward electricity markets reflect these expectations. Power futures for Week 10 traded near €91/MWh, while contracts for March 2026 approached €95/MWh. These levels suggest that traders expect marginal generation costs to remain elevated due to fuel and carbon prices.
The spread between forward electricity prices and spot prices also provides insight into market expectations. When forward prices exceed spot prices, traders anticipate higher marginal generation costs in the future, often due to rising fuel prices or seasonal demand increases.
In Southeast Europe, this forward premium also reflects uncertainty surrounding hydrological conditions and renewable output. A dry season or prolonged cold weather could significantly increase electricity demand and push marginal costs higher.
For electricity traders, understanding the marginal cost structure of the generation stack is essential for forecasting price movements. Changes in gas, coal or carbon prices can shift the dispatch order of power plants, altering electricity prices across the entire region.
As Europe continues its energy transition, renewable generation will gradually reduce the role of fossil fuels in price formation. However, for the foreseeable future, coal and gas plants will remain essential for balancing the grid during periods of low renewable output.
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