Electricity.Trade analysis confirms that January 2026 marked a decisive return of gas as the dominant marginal driver of electricity pricing across South-East Europe. While renewable generation increased materially in several markets and hydro conditions temporarily improved in parts of the Balkans, these factors failed to dislodge gas from its central role in price formation once system stress emerged.
The reassertion of gas marginality was not triggered by absolute scarcity but by expectations of risk. As TTF prices moved from €28–29/MWh at the beginning of January to nearly €41/MWh toward month-end, power markets across Hungary, Romania, Italy, and Bulgaria repriced in anticipation rather than in reaction. Electricity.Trade observed that electricity bids increasingly reflected forward gas risk instead of contemporaneous spot fundamentals.
Hungary and Romania exemplified this shift. Both markets averaged prices above €150/MWh, despite modest demand growth. In Hungary, the system’s 34.03% net import share exposed prices to gas-linked Central European dynamics, while Romania’s declining hydro output removed a critical buffer, forcing gas and imports to set the margin. Electricity.Trade notes that in both cases, price formation became forward-looking, embedding gas volatility before physical constraints materialized.
Italy’s position further reinforced the gas-driven hierarchy. With 61.91% of generation coming from gas and net imports of 2.78 TWh, Italian prices remained structurally elevated at €132.67/MWh. Even during periods of strong renewable output, gas continued to dominate peak pricing, anchoring Adriatic spreads and transmitting volatility laterally into neighboring markets.
Hydro-rich systems briefly resisted this repricing. Greece and Serbia, supported by hydro increases of +155.37% and +186.06% respectively, decoupled from the gas-driven surge. However, Electricity.Trade emphasizes that this insulation was conditional and temporary. Hydro displaced gas only while availability remained high; once flows normalize, marginal pricing rapidly reverts to gas and imports.
The structural implication is clear. Renewable growth has altered average price levels but has not changed marginal price control. Without sufficient dispatchable capacity or storage, intermittent renewables cannot suppress gas pricing during peak or stress periods. Gas therefore continues to define the ceiling, the volatility profile, and the forward curve shape of SEE electricity markets.
Electricity.Trade concludes that gas marginality is no longer cyclical but systemic. Power desks operating in SEE must treat gas as the first-order variable in all pricing, hedging, and risk decisions.
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