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Europe’s Natural Gas Inventories Lag Behind as Elevated Carbon Costs Intensify Winter Energy Inflation Risks

By DataTrack

2026-07-29

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Europe’s natural gas market tightened again in the summer of 2026. As of late July, underground natural gas storage facilities across Europe were approximately 55% full, the lowest level for the same period since 2021. Estimates of the normal seasonal level vary across data providers, with EnergyRiskIQ placing it at approximately 75% and GEF at approximately 67.5%, but both indicate that Europe’s inventory rebuilding is significantly behind schedule. Dutch Title Transfer Facility (TTF) natural gas futures rose sharply in July. ICE Endex data show that the last traded price of the August 2026 contract increased from EUR 43.060 per MWh on July 1 to EUR 63.595 per MWh on July 24, representing an increase of approximately 47.7%. As of 11:28 a.m. GMT on July 28, the price had fallen back to EUR 56.535, but remained approximately 31.3% above its level at the beginning of July.

As natural gas prices rose rapidly, European Union Allowance (EUA) prices remained elevated at close to EUR 80 per metric ton. The combined burden of natural gas and carbon emissions costs is raising production expenses for gas-fired power generation and energy-intensive industries. Ahead of the 2026/27 heating season, Europe therefore faces simultaneous risks involving energy security, industrial competitiveness, and rising inflationary pressure.

Lagging Inventory Rebuilding Reduces Europe’s Winter Supply Buffer

Europe’s underground storage facilities can cover approximately 30% of winter natural gas consumption, providing an important buffer during import disruptions, sudden temperature declines, or demand peaks. High consumption during the 2025/26 winter caused storage levels to fall to approximately 28% at the beginning of the inventory rebuilding season. Although injections continued during the summer, replenishment remained significantly behind normal seasonal levels as of late July.

Under the European Union’s current framework, member states are required to fill underground gas storage facilities to 90% between October 1 and December 1. If high prices, supply disruptions, or technical problems make inventory rebuilding difficult, countries may deviate from the target by up to 10 percentage points. Energy consultancy Wood Mackenzie estimates that even if Qatar restores most of its production capacity by the end of September, European inventories may reach only approximately 75% by November 1. If supply disruptions through the Strait of Hormuz persist, storage levels could fall below 70%. When inventories remain below normal levels, the market has less capacity to absorb severe cold weather, equipment failures, and additional supply disruptions. Traders may also bid more aggressively to secure winter supplies, causing low inventories to be reflected first in higher risk premiums before gradually passing through to physical supply conditions and end-user costs.

Recovering Asian LNG Demand Further Raises Europe’s Inventory Rebuilding Costs

Following the Russia-Ukraine war, Europe sharply reduced its dependence on Russian pipeline gas and shifted toward the global liquefied natural gas (LNG) market. This transition diversified Europe’s sources of supply, while also making the region more exposed to Asian demand, international spot prices, and disruptions along major shipping routes. European LNG imports in July 2026 were estimated at only approximately 6.3 million metric tons, the lowest level since September 2024. Asian demand recovered noticeably over the same period, absorbing approximately 4 million metric tons of U.S. LNG between June and July, a record volume. Some cargoes that might otherwise have been shipped to Europe were consequently redirected to Asia.

Supply risks in the Middle East have further constrained available cargoes. The Strait of Hormuz carries approximately one-fifth of global LNG shipments. With Qatari supply disrupted, Asian buyers must compete for additional cargoes from the United States and other regions, while Europe must pay higher prices to attract deliveries. Europe’s inventory problem has therefore expanded from a regional storage shortfall into global competition between European and Asian markets for limited LNG supplies.

Surging Natural Gas Prices and Elevated Carbon Costs Prevent Industrial Expenses from Falling Quickly

Higher natural gas prices directly raise household heating expenses and corporate gas costs. They also pass through to wholesale electricity prices through Europe’s marginal pricing mechanism. When gas-fired power plants are needed to meet the final unit of electricity demand, their fuel and carbon emissions costs influence the market-wide electricity price. EUA prices remained close to EUR 80 per metric ton in July. Although their increase was smaller than that of natural gas, they continued to raise the emissions costs of gas- and coal-fired power generation. Because coal-fired generation produces more carbon emissions per unit of electricity than gas-fired generation, elevated carbon prices also limit power producers’ ability to reduce fuel expenses by increasing coal-fired output, making it easier for higher natural gas prices to pass through to wholesale electricity prices.

Industries including chemicals, fertilizers, glass, ceramics, paper, steel, and non-ferrous metals simultaneously bear fuel, electricity, and emissions allowance costs. European Commission data show that although industrial natural gas and electricity prices in Europe have fallen from the peak of the 2022 energy crisis, they remain approximately two to four times higher than those of major trading partners. A renewed increase in energy prices would further weaken investment and export competitiveness in Europe’s energy-intensive industries.

Energy Inflation Restricts ECB Policy Flexibility as Winter Temperatures Become a Critical Variable

Wholesale natural gas prices do not usually pass through immediately or proportionately to consumer prices. Corporate hedging contracts, fixed-rate agreements, government subsidies, and pricing adjustment cycles delay the transmission. Energy shocks therefore tend to affect corporate procurement and production costs first, before gradually appearing in merchandise prices, transportation expenses, and household energy bills.

Official data released by Eurostat on July 17 show that the euro area’s Harmonised Index of Consumer Prices (HICP) inflation rate fell from 3.2% in May to 2.8% in June. Energy inflation also declined from 10.8% to 8.5%, but remained an important source of upward pressure on overall prices. On July 23, the European Central Bank maintained its deposit facility rate at 2.25% and stated that the full inflationary impact of the energy shock had not yet materialized. It will continue monitoring the extent to which companies pass on higher costs and whether second-round effects emerge. Consequently, even as economic growth and industrial activity slow, the ECB cannot disregard the effects of energy prices on inflation expectations and corporate pricing. If natural gas prices remain elevated for an extended period, the scope for further monetary easing will be reduced.

Europe still has LNG import capacity, Norwegian pipeline supplies, and lower natural gas demand than in 2022, meaning that a comprehensive supply crisis has not yet emerged in the near term. Risks during the 2026/27 winter will depend primarily on the pace at which shipments through the Strait of Hormuz and Qatari production recover, the strength of Asian LNG demand, and winter temperatures. A mild winter would reduce inventory withdrawals. If supply disruptions continue and Europe experiences a prolonged period of severe cold, natural gas prices, electricity prices, and industrial costs could rise again, increasing the risk that energy-related inflationary pressure persists into the first half of 2027 and further weakening European industrial competitiveness and monetary policy flexibility.

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