The clearest market contradiction in Week 25 was the growing divergence between gas and electricity prices. While TTF futures averaged €41.76/MWh, marking a 14.8% weekly decline, most Southeast European electricity markets moved in the opposite direction. Serbia rose by 9.6%, Hungary by 10.6%, Croatia by 11.2%, Romania by 7.7%, and Italy by 3.7%. This disconnect highlights a key structural reality: lower gas prices do not automatically translate into lower electricity prices when system conditions tighten.
This divergence is increasingly driven by hourly balancing dynamics rather than fuel fundamentals alone. Gas remains an important marginal fuel, particularly in systems where gas-fired generation sets the price, but it is no longer the dominant explanatory factor for short-term power price movements. In Week 25, electricity demand increased by 3.1% to 16.34 TWh, while hydro generation fell by 4.7%, wind output declined by 4.4%, and thermal generation increased sharply by 19.4%. The system required significantly more dispatchable capacity even as fuel input costs declined.
Gas-fired generation rose by 32.3%, adding approximately 771 GWh compared with the previous week. This indicates that gas plants were not only relevant but increasingly essential in covering system needs. Although falling TTF prices helped reduce marginal generation costs, the higher level of thermal dispatch—particularly during evening peak hours—kept wholesale electricity prices elevated across the region.
For industrial buyers, this pattern reinforces an important limitation in procurement strategies that rely primarily on gas price signals. Electricity price formation is now shaped by a broader set of variables, including hydro availability, renewable generation profiles, temperature-driven demand fluctuations, cross-border flows and the timing of evening ramps. A declining gas benchmark can therefore coexist with rising electricity prices when system flexibility becomes constrained.
For generators, the week strengthened the commercial position of flexible thermal assets. Gas-fired plants benefited not only from fuel economics, but from increased dispatch opportunities during periods of system tightness. In this context, value is increasingly determined by availability during scarcity hours, rather than fuel spread alone.
From a policy perspective, Week 25 underscores the distinction between gas market stability and electricity market affordability. Improvements in LNG supply, storage levels and hub pricing can reduce upstream fuel risk, but they do not directly resolve structural electricity challenges such as grid congestion, ramping requirements, renewable intermittency and hydrological variability.
Ultimately, Week 25 reinforced a key structural shift in Southeast European power markets: fuel prices explain part of the story, but system shape, flexibility and timing increasingly explain the rest.