European gas benchmarks extended their rally in Week 42, adding pressure to Southeast European electricity markets as the region approached winter with limited gas-storage headroom, according to Virtu.Energy. The move in European gas prices increased the fuel-cost backdrop for power generation. TTF futures averaged €86.54/MWh, up 11.6% from the previous week.
The TTF benchmark stayed above €84/MWh throughout Week 42 and closed Friday at €87.55/MWh. The one-month forward contract was trading at about €88.40/MWh as the week ended. For electricity markets, these prices indicate the cost of operating gas-fired generators.
Higher fuel costs lift the marginal cost of combined-cycle gas plants and can push wholesale electricity prices higher, including in countries that rely less directly on gas-fired generation. This effect is particularly relevant in Southeast Europe, where gas plants often provide flexibility when wind, solar and hydro output changes. Gas-fired generation can therefore influence regional power prices even when output varies between countries.
Storage levels and gas-fired generation
European gas inventories were at relatively low seasonal levels, with storage expected to enter November at around 75-78%, roughly 10 percentage points below the five-year average. This does not necessarily point to a physical supply shortage, but it leaves Europe with a smaller operational buffer. As a result, markets are more sensitive to disruptions in pipeline or LNG supply.
The region remains dependent on both pipeline imports and LNG, while competition with Asian buyers can quickly affect European hub prices. Week 42 electricity data showed that the relationship between gas and power generation is not uniform across Southeast Europe. Regional gas-fired electricity output fell 7.43%, while Greece’s gas generation rose 26.56%. Croatia also recorded a strong increase in thermal production, entirely from gas.
At high gas prices, some generators cut output as they become less competitive. Others continue operating when local electricity prices, grid requirements or export opportunities make generation commercially viable. For Southeast European electricity traders, TTF remains one of the key external indicators to monitor through winter. If gas prices remain near €90/MWh, gas-fired marginal electricity could stay expensive even during periods of strong renewable generation.
Generation costs and market exposure
Higher gas costs increase the value of coal, hydro, nuclear and renewable generation with lower short-run marginal costs. However, each alternative carries its own constraints: higher coal dispatch increases carbon exposure, while hydro availability depends on water conditions. Renewable output remains weather-dependent, and nuclear production is relatively inflexible and geographically concentrated. Gas therefore continues to provide a flexible back-up mechanism in the region, even when that flexibility is expensive.
Battery storage becomes more valuable when it can displace gas generation during high-price peaks, and demand response becomes more attractive to industrial consumers. Long-term renewable power purchase agreements (PPAs) can shield buyers from fossil-fuel price volatility. Buyers still need solutions for hours when contracted renewable generation is unavailable.
Europe’s gas market and Southeast Europe’s power market are likely to remain closely linked during winter. The main risk is not only whether Europe has enough gas, but whether securing it becomes costly enough to reshape generation dispatch and electricity prices across the Balkans.