Do Europe’s depleted gas stocks point to a new energy crisis?

European gas storage facilities were roughly 60% full in mid-August 2026, almost 20 percentage points below their level around the same time last year, according to figures reported from Gas Infrastructure Europe’s AGSI platform. The shortfall does not mean Europe is running out of gas, but it leaves traders and governments with less time and a narrower margin for rebuilding the winter buffer.

The gap has been forming since a colder 2025-26 winter drew inventories down to 28% of capacity by 1 April. Refilling has subsequently lagged both last year’s pace and the ten-year summer average. In July, the EU Agency for the Cooperation of Energy Regulators, ACER, said storage was around 49% full and warned that reaching 90% would require LNG imports about 13% higher than in 2025. An 80% level remained achievable with last year’s LNG volumes, the agency calculated.

That distinction matters. Storage is insurance rather than Europe’s sole source of gas: the European Commission says underground facilities normally cover about 25% to 30% of winter consumption. Pipeline supplies from Norway, LNG terminals and cross-border trading continue throughout the heating season. A lower starting level therefore raises exposure to adverse events without automatically producing a shortage.

The immediate obstacle is economic as much as physical. Traders normally buy relatively cheap gas in summer, store it and sell it when winter prices rise. This year, conflict in the Middle East and intense competition for LNG cargoes have kept near-term prices elevated and compressed that seasonal price spread. ACER says the resulting weak commercial incentive has slowed injections. Europe may consequently have to pay a premium, offer guarantees or accept a lower buffer to attract additional cargoes before cold weather arrives.

Belgium illustrates both the vulnerability and the resilience of this market. The country’s only underground storage facility, Fluxys Belgium’s Loenhout site, held 1.7 terawatt-hours on 1 June, equivalent to 22% of its firm commercial capacity, according to the Federal Public Service Economy. That compared with substantially higher levels at the same point in recent years. By 23 July, Fluxys told Belga that the filling rate had risen to almost 31%, still well below the EU average at the time.

Loenhout nevertheless has only 7.6 TWh of firm capacity, roughly 5% of Belgium’s annual gas demand. Belgium therefore depends less on its own reservoir than the headline percentage suggests. Fluxys operates a highly interconnected 4,000-kilometre transmission network, while the Zeebrugge LNG terminal can regasify up to 197 TWh annually. Those links allow Belgium to import gas and move it towards Germany, the Netherlands, France and Luxembourg. They also make Belgian security inseparable from conditions across north-western Europe.

For households, lower storage does not immediately change a bill. Customers on fixed contracts have already paid for price protection, while variable contracts pass wholesale movements through with a delay determined by their indexation formula. The risk is that a cold autumn, a prolonged LNG disruption or stronger Asian demand pushes the TTF benchmark higher. Suppliers would then incorporate those costs into new contracts and later indexations. Belgian families heating with gas would feel the effect most directly, while electricity prices could also rise when gas-fired plants set the marginal wholesale price.

Industry faces the same exposure on a larger scale. Chemical, glass, food-processing and metals businesses use gas as fuel or feedstock, and another price shock would further weaken sectors already competing with producers in regions where energy is cheaper. Antwerp’s industrial cluster is particularly sensitive. Unlike in 2022, however, Europe now has more LNG import capacity, lower structural gas demand and established emergency coordination rules. These changes make a repeat of that crisis less likely, though not impossible.

The political choices are uncomfortable. Governments can encourage rapid filling through subsidies or obligations, improving security but potentially making consumers or taxpayers absorb the difference between expensive summer purchases and later market prices. Waiting may produce cheaper gas if tensions ease, but it also leaves less time to respond if supplies tighten. The EU’s extended storage rules retain a 90% objective during a window from 1 October to 1 December, while permitting deviations when market or technical conditions are unfavourable.

Europe is therefore facing a tighter and more expensive winter preparation exercise, not a confirmed new energy crisis. The decisive indicators over the coming weeks will be the rate of storage injections, LNG arrivals, developments in the Middle East, Norwegian supply reliability and early autumn temperatures. Reaching around 80% with steady imports would provide a meaningful cushion. Persistent refilling delays combined with a supply interruption would turn today’s warning into a much more serious threat.