Monitoring of environmental markets by Electricity.Trade shows that EU carbon allowances remain a decisive variable in regional power pricing. On 24 February 2026, EUA December 2026 contracts traded near 71–75 EUR/tCO₂. The level of allowance prices reinforces the cost burden on coal and gas-fired generation across Central and South-East Europe.
Carbon costs and their impact on coal marginal economics
In coal-heavy systems, carbon costs directly affect competitiveness. A coal plant emitting roughly 0.9 tons of CO₂ per MWh faces carbon-related costs exceeding 60 EUR/MWh at current allowance levels. Electricity.Trade analysis indicates that these costs increasingly influence whether coal units run during marginal hours or shift output to gas or imports.
Clean spark spread sensitivity in Hungary and Romania
In Hungary and Romania, gas-fired plants often set marginal prices during peak hours. Carbon pricing interacts with gas costs to define the clean spark spread in these market conditions. On days like 24 February, when Hungarian day-ahead prices exceeded 115 EUR/MWh, the implied clean spark margin remained positive but sensitive to small fluctuations in gas or carbon costs.
Volatility effects from combined fuel and carbon pricing
Electricity.Trade reports that carbon pricing amplifies volatility rather than smoothing it. When wind output declines or demand surges, thermal generation requirements expose markets to combined fuel and carbon cost escalation. During periods of high renewable output, marginal costs drop sharply, compressing spreads.
Regional integration and the need for spread modeling
As SEE markets integrate more deeply with EU structures, carbon pricing is expected to exert increasing influence even in partially coupled systems. Electricity.Trade states that modeling clean spark and clean dark spreads is now indispensable for accurate regional risk assessment.
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