European gas storage injections fall 16% in Q2 as Middle East risks and weak spreads slow refilling
Net flows into underground sites totalled 21.3bcm through June, nearly 11% below the ten-year average and raising the risk of a sub-90% fill by October.
European gas storage injections fell 16% year on year in the second quarter, with net flows into underground sites totalling 236 TWh between 1 April and 30 June, down from 280 TWh in the same period last year and around 11% below the ten-year average, EU energy regulator Acer said late on Tuesday (2026-07-07).5
The weaker refilling pace raises the risk of a tighter start to winter heating season unless injection rates accelerate in the third quarter, the regulator warned, describing the coming months as "challenging."5
Acer attributed the slower injection rate to unfavourable summer-winter price spreads and supply risks linked to Middle East geopolitical tensions. Weak spreads reduced the economic incentive for storage operators to inject gas during the refilling season, while regional volatility has kept global LNG supply tight.5
ICE Endex TTF front-month traded at €49.04 on Wednesday (2026-07-08), while NYMEX Henry Hub front-month held at $3.21 on Thursday (2026-07-09), both showing little immediate reaction to the Q2 data. [live prices]
The 21.3bcm net injection figure compares to a seasonal profile that would require far stronger flows to meet the EU's 90% fill mandate by 1 October. Gas transmission system operators warned in May (2026-05-21) that a "tight LNG scenario" — with 71bcm of imports this summer — would leave storage at only 76% by the deadline, while hitting the 90% target would require an unprecedented 86bcm of LNG imports.3
Entso-G, the gas TSO group, said unplanned maintenance or unexpected disruptions in the global LNG market could place additional pressure on the refilling schedule.3
European buyers face a narrowing window to secure enough LNG cargoes in the third quarter to close the injection gap without bidding up global prices. The risk is asymmetric: a hot summer in Asia or an unplanned outage at a major export terminal would force European storage operators to compete for spot cargoes, likely pushing TTF higher and widening the gap to winter contracts.
Lower-48 US dry gas production sat at 109.3 billion cubic feet per day in mid-May (2026-05-20), up 1.4% year on year and near record levels, while domestic demand reached 73.0 billion cubic feet per day, according to FX Empire estimates. US LNG export flows ran at 17.8 to 18.1 billion cubic feet per day, but seasonal maintenance at export facilities capped feedgas demand and left additional supply available for the domestic market.4
NYMEX June natural gas settled at $2.96 per million British thermal units on Friday (2026-05-15), gaining 2.3% on the day and about 7.4% for the week, supported by weather forecasts and stronger power-sector demand. Weekly vessel departures reached 141 billion cubic feet, up 26 billion from the prior week despite maintenance activity at several facilities.1,2
Acer's Q2 injection data will be scrutinised alongside weekly storage figures in coming months. If net flows remain below the ten-year average through August, the probability of a sub-90% fill by 1 October rises sharply, raising the risk of price spikes once heating season begins. Traders will watch whether summer-winter spreads widen enough to restart commercial injection activity before the seasonal window closes.5,3