Recent analysis of the electricity markets in Southeast Europe during January and February 2026 reveals that the relationship between gas and power generation has not diminished despite the rise of renewable energy sources. Instead, gas-to-power coupling has re-emerged in a more volatile form, underscoring the continued dominance of gas as a marginal price setter during periods of system stress. This trend persists even with significant solar capacity in Hungary, increasing wind energy deployment in Greece and Romania, and enhanced hydro generation in Serbia and Greece.
The prevailing assumption that the growth of renewables would linearly reduce the influence of gas is challenged by market data. While renewables may decrease the frequency of gas dispatch, they simultaneously heighten the intensity of gas price formation when demand peaks. Consequently, there are fewer hours dominated by gas usage, but those hours are marked by extreme pricing fluctuations.
Italy serves as a prime example of this phenomenon, with approximately 61.91% of its electricity generation derived from gas. As a key player in the Adriatic and broader Southeast European energy landscape, Italian power prices remain closely tied to TTF gas benchmarks. This correlation ensures that any rise in gas prices is swiftly reflected in Italian power costs, which then influences neighboring markets through interconnected systems.
The cases of Hungary and Romania illustrate how import dependencies can reinforce gas-to-power coupling. Hungary’s reliance on imports—accounting for about one-third of peak demand—means that marginal pricing is effectively imported alongside electricity. In January 2026, Romania faced a similar scenario; despite having a diversified energy mix including nuclear, wind, and solar, adverse hydro conditions necessitated reliance on gas and imports, pushing prices above €150/MWh.
Hydro-rich countries like Serbia and Greece might seem to disrupt this coupling due to temporary increases in hydro output exceeding +150%, which can lower prices and reduce gas dispatch. However, this decoupling is fragile and contingent on weather conditions. A decline in hydro reservoir levels or inflow rates can quickly revert these systems back to gas-dominated pricing structures.
The integration of solar and wind energy introduces additional complexities to pricing dynamics. These sources tend to suppress midday prices while shifting scarcity into evening and early-morning hours—times when gas generation is essential for meeting demand. Therefore, renewable growth effectively concentrates gas dispatch into fewer hours, amplifying its marginal value and price impact during those critical periods.
While battery storage technologies are beginning to offer some mitigation against these effects, their current scale remains limited. For instance, the 202 MW / 500 MWh Maritsa East 3 battery provides flexibility for only short durations. It can alleviate peak demands but cannot sustain operations through prolonged periods of low wind or cold spells; thus, gas continues to play a vital role in ensuring reliability.
This structural reality is reflected in forward market pricing across Southeast European markets, where gas risk remains embedded even amidst announcements of new renewable capacity additions. The forward market does not account for average renewable output; rather, it focuses on tail risks that remain predominantly influenced by gas prices.
The resurgence of gas-to-power coupling should not be interpreted as a failure of renewable energy initiatives but rather as an inherent characteristic of energy system dynamics. The intermittent nature of renewable generation reduces overall energy scarcity while increasing the demand for flexible resources. Until multi-day flexibility solutions become viable, the role of gas will remain crucial.
In conclusion, while renewable energy expansion has reshaped price structures within power markets, it has not diminished the authority of marginal pricing controlled by gas. The coupling between these two sectors endures but has been compressed into fewer hours characterized by heightened volatility.
