Europe's Gas Storage Hits a 13-Year Low as Winter Approaches
European gas storage stood at 63% full in the final week of August 2026, the lowest level for this point in the calendar since 2013, according to Gas Infrastructure Europe data reported by The Guardian. The shortfall is roughly 17 percentage points below the late-August average of recent years. It follows a steady erosion through the summer: stocks were 57% on August 6, 60.8% on August 15, and 61% by August 19. A year earlier, EU-wide storage stood at 74% of capacity at the same juncture.
Several forces drove the depletion. A US-Israel military campaign against Iran severely disrupted oil and gas exports from the Gulf, choking off a supply route critical to EU refill operations. A cold end to the previous winter drew stocks down further than usual entering the injection season (the spring-to-autumn window when storage operators pump gas back into underground reservoirs). Then summer heatwaves across Europe forced above-normal gas-fired power generation just when operators needed to be injecting, not withdrawing. The cumulative effect left the EU behind the curve with the heating season weeks away.
Germany, which holds Europe's largest underground storage capacity, sat at roughly half-full. Belgium and the Netherlands were in similar straits at 51% and 45% respectively. Italy and Poland, by contrast, topped up to above 80%, leaving a stark divergence in preparedness. The UK presents an extreme case: Chris O'Shea, chief executive of Centrica (owner of British Gas), said the country had almost no gas in storage for the coming winter. The UK ranks among Europe's largest gas consumers but maintains some of the lowest domestic storage capacity, relying on pipeline imports from the continent and LNG (liquefied natural gas) shipments from the US and Middle East.
Europe's benchmark gas price responded accordingly, climbing above €68 per megawatt-hour in recent weeks to three-year highs and more than double the level at the start of 2026. Bjarne Schieldrop, chief commodities analyst at SEB, said the European gas market had run into a winter panic over the past week. Goldman Sachs analysts put the threshold higher still: prices would likely need to exceed €100/MWh to attract sufficient LNG cargoes to meet winter demand without Middle East volumes in the mix.
The trajectory through the back half of summer offers little comfort. Gas analyst and professor Greg Molnar said the EU is likely to enter the winter heating season with stocks about a fifth below the five-year average and at their lowest level since 2013. Reuters reported in early August that forecasts then ranged from a 67–76% peak in pre-winter storage levels. Storage drained to 44% of capacity by January 26, 2026, according to AGSI platform data, meaning the EU started the current injection cycle from a low base and never closed the gap.
For context, EU storage was 76% full in mid-August 2022, a period that itself was considered precarious after Russia's supply cuts. The current 63% sits well below even that benchmark. Gas Infrastructure Europe's AGSI platform, which publishes the underlying storage inventory data, also reported storage levels of 61% as of August 19, 2026, compared with 76% at the same point in 2022.
The geopolitical dimension is central. Middle East LNG and pipeline gas flows were a critical substitution source after Russian pipeline supply collapsed earlier in the decade. With Gulf exports disrupted by the Iran conflict, Europe's ability to attract spot LNG cargoes (shipments bought on the open market rather than through long-term contracts) depends almost entirely on outbidding Asian buyers on price. Goldman Sachs's €100/MWh threshold is effectively the price of rerouting those cargoes absent Gulf supply. At €68/MWh, Europe remains well short of that trigger.
The winter demand outlook adds further pressure. A cold finish to last winter already showed how quickly EU storage can deplete under sustained heating demand combined with power-sector gas burn. If the coming winter produces similar temperature patterns, stocks entering January from a sub-70% starting point could fall to critically low levels well before the spring injection season resumes.
The broader context here is that the combination of a structurally reduced supply base, depleted carry-over stocks, and price-sensitive LNG procurement leaves the EU gas market more exposed than at any point since the 2022–2023 crisis. What distinguishes the current situation from 2022 is the absence of a clear policy lever. During the earlier crisis, EU member states adopted joint gas purchasing, mandatory storage targets, and demand-reduction regulations that helped stabilize the market. Those mechanisms were designed for a world in which Middle East LNG remained available as a swing supplier — a flexible source that can ramp up when others falter. The current supply disruption removes that backstop, and the policy toolkit has not yet adapted to the new geometry. The European Commission has not signaled new emergency measures. Absent a ceasefire in the Iran conflict or an unanticipated surge in non-Gulf LNG supply, the arithmetic of storage refill, price levels, and winter demand points to a tight and volatile market through the heating season.
