European gas prices softened in Week 22, but the move did not break the link between gas and power pricing in Southern Europe. TTF futures averaged €46.56/MWh, down 6.7% week-on-week, after reaching €47.64/MWh on 26 May and settling at €46.00/MWh on 29 May. At publication, the one-month TTF forward traded at €49.200/MWh, equivalent to $16.77/MMBtu. As reported by Electricity.trade, the decline improved sentiment but did not remove a gas premium embedded in power prices where CCGTs stayed marginal.
Italy shows higher power prices despite lower TTF
Italy was highlighted as the clearest case. Even with stronger imports and improved hydro generation, Italian power prices increased by 6.3% to €123.58/MWh. Gas-fired generation rose 25.3%, while total thermal output climbed 32.6%. The data indicated that a lower TTF level does not automatically translate into low gas-related costs for efficient CCGT plants.
The same range of TTF levels was described as still implying high short-run costs for efficient CCGT operation. The assessment referenced the impact of conversion efficiency, carbon costs and operational margins when gas is used in flexible generation. With TTF around €46–49/MWh, the cost implication for CCGTs remained elevated.
Greece and Romania diverge on power outcomes
Greece and Romania also increased thermal generation, largely through gas-fired output. Their price outcomes differed because system balances were not the same across the two markets. Greece had stronger renewables, higher hydro generation and rising exports, which supported power prices at €86.77/MWh.
Romania’s power price fell by 5.1% to €103.46/MWh, but it remained above both Greek and Bulgarian levels. Across the two countries, gas continued to function as an important marginal reference even when national price movements diverged.
LNG supply uncertainty keeps gas prices elevated
The report said the gas market stayed sensitive to geopolitical risk. Prices eased after improved sentiment around the Strait of Hormuz, but remained elevated versus normal seasonal levels. The reason given was that the market continued to price uncertainty about global LNG supply balances.
LNG inflows were described as stable or recovering in parts of Southern Europe, but that did not lead to cheaper gas. Europe was still competing in a global LNG market where Asian demand, Middle East supply risk and storage strategy affected forward pricing.
Implications for procurement and flexible generation
For power buyers, the report described week-on-week TTF declines as potentially reducing pressure without removing procurement risk when absolute gas prices remain high. Industrial consumers exposed to Italian, Greek, Romanian or broader SEE price levels were not able to assume that softer gas would automatically deliver cheap electricity. The key question raised was whether gas plants are marginal during the hours they run or when they hedge.
For generators, the gas-power link was described as supporting value for flexible thermal assets, particularly where wind underperforms or evening demand tightens. For battery investors, it was linked to an arbitrage case because gas-linked evening prices can remain high even when solar depresses midday prices.
Week 22 keeps a gas premium in southern power pricing
The overall picture for Week 22 was that gas was softer while still decisive for power pricing signals across Southern Europe. With TTF at €46.56/MWh, the market was described as not low enough to reset Southern European power economics. Instead, it reduced pressure in a system still priced around scarcity, flexibility and fuel risk.
