European gas prices softened in Week 22, while the link between gas and power pricing in Southern Europe remained intact. TTF futures averaged €46.56/MWh, down 6.7% week-on-week, after reaching €47.64/MWh on 26 May. The contract closed 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 supported market sentiment but did not remove the gas premium embedded in power prices where CCGTs stayed marginal.
Italy sees higher power prices despite stronger imports and hydro
Italy provided the clearest example of how lower TTF did not translate into lower power pricing. Italian power prices rose 6.3% to €123.58/MWh, despite stronger imports and improved hydro generation. Gas-fired generation increased 25.3%, while total thermal output rose 32.6%.
The figures indicate that a lower TTF price is not the same as a low TTF price for power economics. With TTF around €46–49/MWh, gas still implied a high short-run cost for efficient CCGT plants when conversion efficiency, carbon costs and operational margins were included.
Greece and Romania increase thermal output with different price results
Greece and Romania also increased thermal generation, largely driven by gas-fired output. Their price outcomes differed because broader system balances differed across the two markets. Greece had stronger renewables, higher hydro and rising exports, which helped keep prices at €86.77/MWh.
Romania’s power price declined 5.1% to €103.46/MWh, but it remained above both Greek and Bulgarian levels. In both cases, gas continued to act as an important marginal reference even when country-level price moves diverged.
LNG supply uncertainty keeps gas prices elevated despite easing sentiment
The gas market remained sensitive to geopolitical risk during the period. The report said prices eased after improved sentiment around the Strait of Hormuz, but stayed elevated versus normal seasonal levels because uncertainty around global LNG supply balances was still being priced.
LNG inflows were stable or recovering in parts of Southern Europe, but this did not lead to cheap gas. Europe continued competing in a global LNG market where Asian demand, Middle East supply risk and storage strategy influenced forward pricing.
Implications for procurement, dispatch and flexibility value
For power buyers, a week-on-week fall in TTF could reduce pressure, but procurement risk remained high while the absolute gas price stayed elevated. Industrial consumers exposed to Italian, Greek, Romanian or broader SEE prices could not assume that softer gas would automatically deliver cheaper electricity.
The key operational question was whether gas plants were marginal during the hours they ran or when they were hedged. For generators, the gas-power link supported value for flexible thermal assets, particularly where wind underperformed or evening demand tightened.
The same linkage also supported the battery arbitrage case because gas-linked evening prices could remain high even when solar reduced midday prices. Week 22 showed gas softer than before but still decisive for regional pricing dynamics.
TTF at €46.56/MWh was not low enough to reset Southern European power economics; it mainly reduced pressure in a market still priced around scarcity, flexibility and fuel risk.
