Europe’s Low Gas Storage Threatens High Winter Energy Bills

The difference amounts to more than a statistical warning. Europe has spent four years reducing its dependence on Russian pipeline gas, replacing much of that supply with LNG delivered through international shipping networks. That has broadened its sources of energy, but it has also made the price of keeping European homes and factories supplied increasingly dependent on events far beyond the continent.

A Smaller Cushion Against Winter Demand

Europe's underground storage facilities held approximately 845 terawatt-hours of gas on 21 October, below the five-year seasonal norm of 86%. The relatively weak position follows a difficult summer replenishment period, during which high wholesale prices and unfavourable seasonal price differences discouraged traders from putting additional gas into storage.

Normally, companies have an incentive to buy gas during warmer months, when demand is lower, and sell it during winter at higher prices. That calculation becomes less attractive when summer gas is already expensive or the expected winter premium is insufficient to cover storage costs.

By 1 October, European storage was only 72% full. The subsequent increase has done little to close the gap with previous years.

National figures also conceal significant differences in preparedness. Poland entered the period with storage at 98.8% of capacity, Portugal at 95.5% and Italy at 90.2%. Germany, Europe's largest economy, had filled just 61.1% of its storage capacity, equivalent to 143.6 TWh out of 247.5 TWh. The Netherlands stood at 65%.

These disparities matter because the economic consequences of a difficult winter will not be evenly distributed. Countries with smaller reserves may need to rely more heavily on additional imports or supplies available through the interconnected European gas network.

Yet the European Commission and the European Network of Transmission System Operators for Gas, ENTSOG, do not anticipate an immediate systemic supply deficit under baseline winter conditions.

Europe has developed a more diversified import network, including LNG regasification infrastructure with estimated seasonal capacity of around 145 billion cubic metres. That provides flexibility unavailable during the earlier period of heavy reliance on Russian pipeline deliveries.

Infrastructure, however, cannot guarantee that internationally traded gas will be available at an affordable price.

The Strait of Hormuz Has Become a European Energy Risk

The greatest external uncertainty comes from the Middle East, where security and shipping disruptions around the Strait of Hormuz have affected LNG exports from Qatar and the United Arab Emirates.

The disruption has constrained flows through a route associated with nearly one-fifth of global seaborne LNG trade. For European buyers, the consequences extend beyond the immediate loss or delay of individual shipments.

LNG is traded internationally, and cargoes can be directed towards markets offering more attractive commercial terms. When supplies tighten, European importers must compete with buyers elsewhere, particularly in Asia, where demand has been increasing.

This creates a fundamentally different form of exposure from the pipeline dependence that dominated European energy policy before Russia's full-scale invasion of Ukraine.

Pipeline supplies created concentrated political and commercial relationships with particular exporters. LNG offers a broader selection of suppliers, but its flexibility also means that Europe competes more directly with other major importing regions.

A disruption affecting Gulf exports can therefore influence European prices even when the affected shipments were not originally intended for European terminals.

The market responds to the availability of gas globally, rather than simply to the volume already contracted by European companies.

For policymakers, this complicates the meaning of energy diversification. A wider supplier base reduces dependence on any single country, but does not remove exposure to maritime bottlenecks, geopolitical instability or competition for cargoes.

Europe has diversified its suppliers without insulating itself from the global market.

The Industrial Cost of Energy Security

Financial forecasts illustrate how quickly a manageable supply position could become an economic problem.

Goldman Sachs and Morningstar projections cited in the briefing place benchmark European TTF gas prices at approximately €60–€70 per megawatt-hour under baseline conditions.

More severe scenarios involving prolonged Middle Eastern supply disruptions or unusually cold weather could push prices towards €90–€120/MWh, with extreme estimates reaching €150/MWh.

These are conditional projections, not expected outcomes. Their importance lies in the scale of the potential difference between a relatively stable winter and one marked by simultaneous supply and demand pressures.

For households, higher wholesale prices can eventually translate into more expensive heating and electricity, depending on national tariffs, contracts and government protections.

For energy-intensive manufacturers, the impact can be more immediate.

Chemical producers, fertiliser manufacturers, glassmakers and metal-processing companies depend heavily on competitively priced energy. Sustained increases in gas costs can reduce margins, weaken competitiveness and force businesses to reconsider production levels.

Europe's industrial challenge is therefore closely connected to its energy procurement strategy.

Replacing Russian pipeline gas with diversified imports has strengthened the continent's ability to respond to political pressure from a single supplier. It has not necessarily restored the low and predictable energy costs on which parts of European manufacturing previously relied.

That distinction is particularly important for Germany, where relatively low storage levels coincide with a substantial industrial requirement for gas.

Higher import prices would create pressure beyond the energy sector itself, potentially affecting production decisions, investment and the competitiveness of European goods.

The Price of Closing the Storage Gap

The Institute for Energy Economics and Financial Analysis estimates that compensating for Europe's weaker storage position could require a reduction of roughly 7% in winter gas demand, equivalent to approximately 14 billion cubic metres, or additional imports costing as much as €3 billion.

Those alternatives expose a difficult economic trade-off.

Additional imports can preserve consumption, but increase the amount Europe must spend securing energy on international markets. Lower demand reduces import requirements, but the economic effect depends on where and how that reduction occurs.

Efficiency improvements and voluntary conservation are different from factories cutting production because energy has become too expensive.

Both reduce measured gas consumption. Only the former necessarily represents an improvement in the efficiency of the European economy.

The distinction matters because market adjustments can create an appearance of successful energy balancing even when part of that balance comes from reduced industrial activity.

Europe may have enough gas to satisfy essential demand while still experiencing substantial economic damage from the price required to secure it.

This is why storage percentages alone provide an incomplete measure of energy security.

A country can hold significant reserves yet remain vulnerable to high replacement costs. Conversely, an importer with lower storage levels may be able to maintain supplies through functioning international markets, although potentially at considerable expense.

The Russian LNG Deadline Adds Another Constraint

Europe's planned prohibition on Russian LNG imports from January 2027 introduces a further complication into the winter procurement environment.

Since 2022, the EU has progressively restructured its energy relationships, reducing Russian pipeline imports while expanding purchases from alternative suppliers, including Norway and LNG exporters.

The coming restriction represents another stage of that transition.

Its significance is not limited to the direct removal of Russian LNG from Europe's available supply options. It also reinforces the need for European buyers to secure alternative volumes during a period of heightened global competition.

Non-Russian pipeline suppliers such as Norway stand to retain considerable commercial importance. Global LNG exporters and traders may also benefit when tighter markets increase demand for available cargoes.

For European importers, the challenge is to preserve diversification without allowing procurement costs to undermine the economic benefits of reliable energy access.

The transition also changes the balance of commercial influence.

Where Europe's earlier dependence gave major pipeline suppliers substantial leverage, today's market gives international LNG exporters, traders and competing buyers greater influence over the price at which additional supplies become available.

European governments can expand terminals, improve interconnections and coordinate storage policy. They have much less direct control over demand in Asia or security conditions along Middle Eastern shipping routes.

Storage Is No Longer the Whole Measure of Resilience

Ukraine offers a different perspective on the importance of physical reserves. Its underground storage held nearly 16 billion cubic metres of gas in late October, above the government's minimum target of 13.2 billion cubic metres and reportedly the highest level in six years.

The figure illustrates the continuing strategic value of maintaining substantial inventories, particularly for countries exposed to severe security risks.

Across the EU, however, the winter challenge extends beyond the volume already held underground.

European infrastructure and diversified supply arrangements provide a degree of protection against physical shortages. The more difficult question concerns the price of using that flexibility when international supply is constrained.

A mild winter could ease demand and reduce pressure on imports. Severe cold, combined with prolonged disruption to Gulf LNG exports, would produce a much more difficult market environment.

Neither outcome is predetermined by the current storage figures.

The bigger change is that Europe's ability to maintain secure gas supplies increasingly depends on conditions in a global market that it cannot control.