Amid supply disruptions in the Middle East and ongoing tensions in the Strait of Hormuz, Europe not only lost the global LNG competition this summer but now faces a critical situation with inventories plummeting to just 10% amid the prospect of a harsh winter.
Europe is entering the heating season with significantly low natural gas inventories. Even if the Iran conflict ends during winter and temperatures are not unusually cold, European households and industries may still face high gas prices for at least another year, amid disrupted Middle Eastern LNG supplies and intensifying global spot market competition.
Industry institutions expect that by November 1, European gas storage fill rates may reach only 75%–78%, about 10 percentage points below the five-year average for this time of year. More critically, the current low inventory levels are not solely due to weather, but also result from constrained replenishment capacity this summer, limited by global LNG supply disruptions and abnormal price structures.
A recent Reuters survey suggests that Europe is not currently facing an immediate natural gas shortage, but its buffers for handling extreme cold or sudden supply disruptions have significantly diminished.
Middle East LNG shipments were disrupted, and Europe failed to replenish its inventories throughout the entire summer.
This year, European benchmark natural gas prices have risen more than 150% cumulatively. The primary shock stemmed from restricted transportation near the Strait of Hormuz, severely impacting Qatar and the UAE, which together account for nearly 20% of global LNG exports.
These Middle Eastern LNG shipments were originally mostly destined for Asia, but after supply decreased, Asian buyers turned to other sources, competing with Europe for spot cargoes from the U.S., Canada, Nigeria, and elsewhere. As a result, Europe was unable to replenish its inventories fully during the summer low-demand period, as it typically does.
Increased U.S. LNG exports have eased some of the pressure. With more U.S. shipments redirected to Europe rather than Asia, the Atlantic shipping routes have shortened, and rising deliveries of new LNG vessels have begun to lower freight rates. However, this only partially offsets the supply gap in the Middle East.
Europe's winter consumption heavily relies on inventories. Under normal conditions, underground storage facilities supply approximately 25%–30% of the EU’s winter natural gas demand, with the remaining demand met by pipeline gas from sources such as Norway and imported LNG.
Therefore, the current risk is that Europe’s natural gas safety margin is too small. In the event of a cold snap, major pipeline failure, further disruption to LNG shipments, or a sudden surge in Asian demand, Europe will have to compete for spot supplies at higher prices.
A cold winter could reduce inventory levels to 10%–15%.
LSEG estimates that even if winter temperatures this year are near normal, Northwest European inventories could drop to around 20% by early next April.
The stress scenarios presented by ABN Amro are more severe. If a cold winter occurs, European gas storage levels could fall to 10%–15%. While this level does not necessarily imply an immediate supply disruption, it would make the task of replenishing stocks by summer 2027 exceptionally challenging.
This is also the real concern in today’s market: the energy issue may extend beyond this winter into next summer.
If Europe ends the heating season next spring with extremely low inventories, it will need to purchase large volumes of LNG in the following months to replenish stocks. Even if the Iran conflict eases by then, this additional restocking demand could keep natural gas prices elevated.
ICIS expects that even if the Middle East conflict ends in winter, the market has not yet fully priced in Europe’s restocking demand for 2027. BNP Paribas believes that, following this year’s LNG supply shock, the European natural gas market may not return to its pre-conflict state until 2028.
Germany has low inventory levels, but regulators say there is currently no risk to supply security.
Germany is Europe's largest natural gas storage market and one of the most closely watched countries today.
Germany's gas storage levels are significantly lower than usual for this time of year. On October 15, the German Federal Network Agency stated that the recent slow pace of gas injections is related to market trading strategies, and regulators are "closely monitoring" the situation, though they do not currently consider it a direct threat to supply security.
The problem is that Europe’s traditional gas storage business model is itself breaking down. Previously, traders typically bought cheaper natural gas in the summer and stored it underground, selling it at higher prices in the winter. However, in recent years, the price spread between summer and winter futures has narrowed significantly, and at times has even inverted, with summer prices exceeding winter forward prices.
Under this structure, commercial entities actively storing gas may mean incurring losses. After a significant reduction in Russian pipeline gas, Europe has become increasingly dependent on the more price-volatile global LNG market. As a result, countries such as Germany and the Netherlands have begun discussing strategies including strategic gas reserves, government subsidies for storage, and mandatory inventory requirements.
The EU’s current strategic natural gas reserves remain small. Most inventories are held by private companies, and governments do not directly control large volumes of natural gas as they do with strategic oil reserves; therefore, market prices still determine whether companies are willing to replenish their stocks.
High gas prices are beginning to spread to households and industries.
The increase in wholesale natural gas prices this year has not yet been fully reflected in residential bills, as many retail contracts in Europe have fixed terms.
Data from the German price comparison platform Verivox shows that new customer gas prices have risen from approximately 8 cents per kilowatt-hour to 12.4 cents per kilowatt-hour this year, an increase of about 55%. As existing contracts expire, current customers may face price increases of 10% to 20% in the future.
The UK is in a similar situation. The consultancy Cornwall Insight expects the household energy price cap, which rose to a three-year high in October, could increase by another approximately 16% in January next year.
The industrial sector faces more direct pressure. Before this crisis, natural gas costs in Europe were already significantly higher than in the U.S., and chemical, fertilizer, glass, and other energy-intensive industries have already experienced declining competitiveness. If natural gas prices remain high over the long term, some companies may further reduce production.
The European Union is also adjusting its energy policy. The European Commission has proposed delaying by one year the new methane emission rules for oil and gas imports, originally set to take effect in 2027, to reduce the risk of these new regulations impacting imports amid current supply constraints.
Europe is currently facing not an immediate supply disruption crisis like in 2022, but rather a prolonged environment of low inventories, high prices, and minimal buffers. This winter’s weather intensity, the shipping situation in the Strait of Hormuz, and whether the U.S. can sustainably increase LNG supplies will determine how low Europe’s gas storage levels can fall by the end of this heating season. The amount of natural gas remaining come next spring may be more decisive for 2027 energy prices than the winter itself.