The EU has almost eliminated its critical dependence on Russian pipeline gas, only to discover another vulnerability: Europe’s energy security now depends on the Strait of Hormuz, U.S. LNG plants, Asian demand, the weather, and several chokepoints in global trade. The winter of 2026–2027 could become the first serious test of Europe’s new energy model.
In August 2026, Europe found itself confronting a paradox that only a few months earlier would have seemed almost impossible. The continent had made it through a cold winter without its energy system collapsing, sharply reduced its dependence on Russian pipeline gas, built new LNG terminals, strengthened interconnections between national gas markets, and received record volumes of U.S. liquefied natural gas. It seemed that the main lesson of the 2022 crisis had been learned.
But the problem returned from another direction.
By August 9, Europe’s underground gas storage facilities were approximately 59% full. Germany, the EU’s largest economy and one of the continent’s most gas-dependent industrial centers, was at only about 48%. Those levels were far below the previous year’s. At the same time, the European benchmark TTF gas price was hovering at roughly €50–€60 per MWh and rose above €60 amid extreme heat and renewed disruptions.
For comparison, at the beginning of 2026 gas was trading at approximately €28–€40 per MWh. In other words, the problem is not that Europe has physically run out of gas. The problem is that the cheap summer gas on which the traditional winter preparation model depended has disappeared.
That is precisely why the current crisis is more dangerous than storage figures suggest. Europe has not returned to 2022. It has entered a new risk environment in which a shortage in the Persian Gulf, extreme heat in Asia, a U.S. hurricane, maintenance on a Norwegian offshore platform, or a windless week in Germany can almost instantly alter the cost of heating, electricity, fertilizers, metals, and industrial production thousands of miles away.
Europe Defeated Gazprom and Ended Up Dependent on Hormuz
After February 2022, the EU carried out perhaps the largest restructuring of energy logistics in its history.
The Russian supply model was built primarily around pipelines and long-term relationships. Europe bought large volumes of gas through physically fixed routes: Nord Stream, Ukraine’s gas transmission system, Yamal-Europe, and TurkStream. The system had one obvious geopolitical weakness: dependence on a single major supplier.
After severing much of those ties, the EU turned to diversification.
In 2025, Norway accounted for 54.4% of European pipeline gas imports, Algeria for 18.5%, and Russia for 9.8%. But something else matters even more: nearly half of the gas imported by the EU now arrives as LNG. In the first quarter of 2026, the United States accounted for 57.4% of EU LNG imports. Russia’s share was 17.3%, Qatar’s 6.6%, and Nigeria’s 6.2%.
At first glance, this looks like a much safer system. An LNG tanker can be rerouted. A terminal can receive cargo from the United States, Nigeria, Algeria, Angola, or another producer. A pipeline cannot simply change its route.
But LNG’s mobility has a downside: cargo goes wherever the buyer is willing to pay the most.
This is where Europe traded one form of dependence for another.
Before 2022, the main risk was political: What will Moscow do?
In 2026, the question is far more complicated: What happens simultaneously in Washington, Tehran, Doha, Beijing, Tokyo, Seoul, Oslo, the Gulf of Mexico, and Europe’s electricity market?
The new energy security system is geographically diversified but financially globalized.
Storage at 58–59%: Why One Number Is Frightening the Entire Market
Europe’s underground storage facilities can hold slightly more than 102 billion cubic meters of gas. During a normal winter, withdrawals from storage can cover as much as 30% of consumption. This is not a reserve large enough to carry the EU through an entire heating season without imports. Storage is a buffer designed to smooth out seasonal surges in demand.
And that buffer has become unusually weak.
On April 1, when Europe’s summer gas season begins, storage facilities were only about 28% full, equivalent to roughly 29 billion cubic meters. The reason was the cold winter of 2025–2026, during which Europe drew heavily on accumulated reserves.
Under normal market conditions, that would not have been catastrophic. Heating demand falls in spring and summer, gas becomes cheaper, traders buy it, inject it into storage, and sell it at a higher price in winter.
But in 2026, that mechanism broke down.
Not physically. Financially.
After the war involving Iran began, gas prices surged. The market then moved into what is known as backwardation, a situation in which near-term gas prices are higher than prices for contracts covering more distant months.
For a storage operator, that kind of price curve sends an almost absurd signal. The operator is being asked to buy expensive gas today, pay for transportation, injection, storage, and financing, and then potentially sell it for less in winter.
The market is effectively telling the operator: do not fill the storage facility.
In early August, Aurora Energy Research assessed the economic incentive for storage injections as virtually nonexistent. Reaching even an 80% storage level would require near-record injection rates and probably government intervention.
This is one of the central paradoxes of European energy policy: governments need inventories for security, while the current price structure gives the market little economic incentive to build them.
Brussels Has Already Rewritten the Rules: 90% on Paper, Potentially 80% in Practice
After the energy shock of 2022, the EU introduced a mandatory target of filling gas storage facilities to 90% before winter.
But Europe quickly discovered the downside of imposing a rigid deadline. If the market knows that dozens of countries are required to purchase enormous volumes of gas by a specific date, sellers gain tremendous leverage. The mandatory purchasing requirement itself can drive prices higher.
The rules were therefore relaxed in 2025.
The legal target of 90% remained in place, but it can now be met at any point between October 1 and December 1. Under difficult conditions, a deviation of 10 percentage points is permitted, and if unfavorable market conditions persist, the European Commission can authorize as much as five additional percentage points of flexibility.
The economic logic is obvious: Brussels is trying to avoid turning energy security into a guaranteed windfall for traders.
But the situation in August demonstrates the limits of that approach.
As early as July, the European Union Agency for the Cooperation of Energy Regulators warned that reaching 90% would require Europe to increase LNG imports by roughly 13% compared with 2025. If imports remained at last year’s levels, approximately 80% appeared more realistic.
By early August, market forecasts had become even more cautious. Analyst estimates compiled by Reuters projected that inventories could peak before winter at only 67–76%.
That is no longer merely a technical deviation from an attractive Brussels target.
It means reducing Europe’s strategic cushion by tens of billions of cubic meters.
A Single Strike on Ras Laffan Changed the Global Market for Years
Europe’s second problem lies roughly 3,000 miles from Brussels, in Qatar.
Ras Laffan is the world’s largest LNG production hub. Iranian strikes in March damaged two of its 14 liquefaction trains and one gas-to-liquids facility. QatarEnergy CEO and Minister of State for Energy Affairs Saad al-Kaabi said approximately 12.8 million metric tons of annual LNG capacity had been taken offline, equivalent to roughly 17% of the country’s export capacity.
The damaged trains are estimated to require three to five years to restore. Lost annual revenue was estimated at approximately $20 billion. Export capacity for condensate, liquefied petroleum gas, helium, and other products was also affected.
This matters for two reasons.
The first is obvious: the global market lost a significant volume of supply.
The second is far more important: the strike hit a producer that was expected to become one of the principal sources of the coming LNG surplus.
Before the war, markets expected a massive expansion of Qatar’s North Field, bringing new Qatari supply online alongside growing U.S. capacity. It was precisely this anticipated wave of new LNG that had created expectations of cheaper gas in the second half of 2026 and beyond.
The International Energy Agency now estimates that the Middle East conflict will reduce potential LNG supply over 2026–2030 by approximately 140 billion cubic meters relative to the previous trajectory. The impact is expected to be greatest in 2026 and 2027.
In other words, Europe is not confronting only today’s shortage.
The war has partially destroyed the future gas surplus that markets had expected to provide relief from high prices.
Hormuz Matters More Than Qatar: Europe and Asia Are Competing for the Same Tanker
There is another paradox.
Europe itself was not the primary buyer of Qatari LNG. In the first quarter of 2026, Qatar accounted for only 6.6% of European LNG imports. During the previous winter, Qatari volumes represented approximately 7% of EU LNG imports and only about 4% of total natural gas imports.
Why, then, has the war hit Europe so hard?
Because the gas market is global.
Before the war, nearly 20% of global LNG supply passed through the Strait of Hormuz. Qatar and the United Arab Emirates have virtually no full-scale alternative to that route. The International Energy Agency estimates that more than 300 million cubic meters per day of gas flows could potentially be blocked. That is approximately twice the average volume carried by Nord Stream in 2021.
Nearly 90% of the LNG that passed through Hormuz in 2025 was headed to Asia.
That is why Europe’s direct supply shortage is only half the story.
When China, Japan, South Korea, India, and other Asian consumers lose Qatari cargoes, they enter the market for U.S., African, and Australian LNG.
The very same gas Europe needs to fill its storage facilities.
From March through June, LNG supplies from Qatar and the United Arab Emirates fell by approximately 35 billion cubic meters year over year. Producers outside the Gulf managed to increase output by nearly 27 billion cubic meters, offsetting roughly three-quarters of the loss. But even that was not enough: global LNG production during the period still fell by approximately 4%.
This is how Europe’s new dependency is taking shape.
It is not called Gazprom.
It is called the global price of the last available LNG tanker.
Why Oil Is Withstanding the War Better Than Gas
Oil and gas markets are reacting to the Middle East crisis in fundamentally different ways.
Oil has a well-developed system of strategic reserves. Governments can release hundreds of millions of barrels onto the market, temporarily offsetting supply disruptions.
There is no comparable global reserve for LNG.
Gas is more difficult to store. Infrastructure is tied to specific terminals. LNG production requires enormous facilities that cannot be built in a matter of months. The tanker fleet is limited. Rerouting cargoes increases shipping distances, freight costs, and delivery times.
An oil shock can therefore be partially absorbed by inventories, while the gas market turns a physical shortage of only a few percentage points of supply into a sharp price movement much more quickly.
The International Energy Agency had expected new projects in North America, Africa, and Australia to add nearly 50 billion cubic meters of LNG supply in 2026, while existing facilities were expected to contribute more than another 10 billion cubic meters. But those volumes are now needed not to create the anticipated surplus, but to plug the hole left by the Middle East crisis.
That is a fundamental shift.
Before the war, 2026 was supposed to mark the beginning of a period of relief.
Instead, it has become the year in which additional supply barely compensates for what has been destroyed.
America Saved Europe From Russia and Gained Enormous Leverage
The United States has emerged as the biggest winner from Europe’s energy restructuring.
In 2021, U.S. LNG was merely one of several sources of European imports. By the first quarter of 2026, the United States supplied 57.4% of all LNG imported by the EU. According to the European Union Agency for the Cooperation of Energy Regulators, U.S. supplies have already become a central component of Europe’s gas balance.
This does not mean Washington can use LNG in the same way Moscow used pipeline dependence. The U.S. market operates differently: supplies are provided by private companies, many contracts have flexible structures, and trade responds to commercial price signals.
But the geopolitical effect is still enormous.
European energy security is now tied to U.S. export policy, the construction of new terminals, domestic Henry Hub prices, pipeline capacity serving export plants, weather in the Gulf of Mexico, and even decisions by the U.S. administration on permits allowing export facilities to expand capacity.
Since the Middle East crisis began, Washington has already authorized Plaquemines LNG to increase its export capacity by approximately 4.6 billion cubic meters per year and Elba Island by roughly 0.8 billion cubic meters.
President Trump is therefore both a participant in the war that triggered the energy shock and the leader of the country whose additional supplies Europe needs to mitigate its consequences.
In energy geopolitics, paradoxes like these are rarely incidental details. They create bargaining power.
Russia Lost the European Market but Gained the Perfect Propaganda Narrative
In Moscow, current developments are being portrayed as confirmation of an argument the Kremlin has repeated since 2022: that Europe’s rejection of Russian gas would supposedly lead inevitably to expensive energy and the erosion of industrial competitiveness.
Kirill Dmitriev, head of the Russian Direct Investment Fund and the Russian president’s special representative for investment and economic cooperation with foreign countries, seized on the August storage figures to warn of a new European energy crisis and blame the EU itself.
For Russian information policy, it is an almost perfect narrative.
But the economic chain of causation is more complicated.
Russia is not the direct cause of the current price surge. The primary factors are the war involving Iran, the effective closure of Hormuz, damage to Qatari infrastructure, competition for LNG, and extreme weather conditions.
Moreover, Europe’s infrastructure is objectively more resilient today than it was four years ago.
But Moscow does have one serious argument: abandoning Russian pipeline gas has indeed made Europe more sensitive to global LNG prices.
And there is another irony that is uncomfortable for Brussels.
During the first five months of 2026, EU imports of Russian pipeline gas increased 7% year over year, while imports of Russian LNG rose 11%. After the first stage of restrictions took effect, imports of Russian LNG under permitted long-term contracts increased even faster. The European Union Agency for the Cooperation of Energy Regulators attributes this in part to the need to compensate for the near-total disappearance of Qatari volumes.
At the same time, the EU intends to end Russian LNG imports completely by the end of 2026 and phase out the remaining pipeline supplies later under the already adopted REPowerEU framework.
The result is an almost surreal arrangement: Europe is temporarily using additional Russian molecules to mitigate a crisis caused by the loss of Qatari molecules while simultaneously closing off the Russian source through legislation.
Politically, Brussels’ logic is understandable.
From the standpoint of the winter gas balance, however, it reduces the number of fallback options precisely when the market is at its most unstable.
Heat Has Proved Just as Dangerous as Cold
There is another factor undermining the old seasonal model.
Gas has traditionally been associated with winter heating. But in the summer of 2026, extreme heat itself became a source of additional gas demand.
During the August heat wave, French nuclear power plants faced operating constraints because of high temperatures and low river levels. The potential reduction in capacity was estimated at as much as 7.3 GW.
At the same time, German wind power generation during some periods was approximately 60% below the seasonal norm. Gas-fired power plants had to compensate for part of the shortfall. French and German day-ahead electricity prices climbed to approximately €140 per MWh and above.
This is a crucial point.
The expansion of solar and wind power is reducing average annual gas consumption. The International Energy Agency expects European natural gas demand to fall by more than 2% in 2026.
But lower average consumption does not necessarily mean lower gas prices at critical moments.
If the wind fails to blow for several consecutive days, hydropower generation declines, nuclear plants reduce output, and extreme heat drives up air-conditioning demand, gas-fired generation becomes the balancing source.
Gas may account for a smaller share of the energy mix while still remaining the fuel that sets the price of the marginal megawatt-hour.
That is one of the most uncomfortable features of Europe’s energy transition: demand for gas is falling faster than electricity prices are becoming independent of gas.
Industry Could Lose the Crisis Before Homes Ever Go Cold
The biggest mistake in discussing the winter of 2026–2027 is reducing the problem to a single question: will there be enough gas to heat people’s homes?
Under the baseline scenario, there most likely will be.
Europe has more LNG terminals, better interconnected gas networks, significantly lower gas consumption than before the 2022 crisis, and a far more diversified supply system.
But an energy crisis does not necessarily begin with empty pipelines.
It can begin with price.
Since the outbreak of the Middle East war, the energy shock has already pushed inflation higher in the eurozone. In May, inflation reached 3.2%, with the European Central Bank explicitly linking the acceleration in the headline rate to rising energy costs.
For a household, gas at €60 is painful.
For producers of ammonia, fertilizers, glass, ceramics, steel, chemicals, and parts of the nonferrous metals industry, it can alter the economics of the entire business.
Even before the current war, European industrial groups were warning that energy costs in the EU were more than twice the levels faced by many competitors in the United States and China. BASF, ArcelorMittal, Heidelberg Materials, and other companies have linked high energy prices to the relocation of capital investment and the erosion of European manufacturing competitiveness.
Gas is not only a fuel. It is also a feedstock for the chemical industry.
The International Energy Agency is already tracking the spillover of the Middle East gas shock into the nitrogen fertilizer market. Higher gas prices are reducing operating rates at ammonia and urea plants in Europe and Asia, while supply disruptions from Gulf countries are adding further price pressure.
This is how an energy crisis turns into a food crisis.
First, gas becomes more expensive.
Then fertilizers.
Then agricultural products.
After that, the pressure feeds back into consumer inflation.
Winter 2026–2027: From Expensive Stability to a Full-Blown Crisis
Europe does not face a single winter scenario. There are several possible trajectories, and the difference between them depends on only a handful of variables.
The first scenario is manageable.
The Strait of Hormuz gradually returns to normal operations, supplies from undamaged Qatari and UAE capacity recover, U.S. exports remain high, and the winter is average or mild.
Under those conditions, even storage levels of 70–80% could prove sufficient. Europe would pay more than it expected to pay last winter, but there would be no physical supply crisis.
The second scenario is an expensive winter.
Hormuz operates only partially, the recovery of Qatari exports proceeds slowly, and temperatures are colder than normal.
Energy Aspects estimated that, under a scenario of gradual market normalization, winter gas prices could plausibly remain in the range of roughly €60–€80 per MWh.
That is not 2022, when spot prices briefly surged above €300.
But for European industry, several months of gas at €70–€80 may be far more dangerous than a short-lived panic spike. Investment decisions are not based on the highest price reached on a single day. They are based on expected energy costs over the years ahead.
The third scenario is a stress case.
Qatari supplies remain severely constrained, Hormuz does not normalize, and the winter is cold.
Under that combination, model-based estimates allow for an average gas price of around €110 per MWh from November through March, with storage levels falling to approximately 10% by the end of winter.
At that point, the discussion would shift to industrial demand curtailment, subsidies, emergency government purchases, and growing political pressure on national governments.
The fourth scenario is a cascading crisis.
It does not require one enormous event.
Several medium-sized shocks would be enough.
A hurricane constrains U.S. LNG exports. A Norwegian field goes offline for unplanned maintenance. Europe experiences a prolonged period of cold, cloudy, and windless weather. Another incident hits gas infrastructure. Russian supplies decline faster than expected. Asian buyers bid up the price of available cargoes.
Each of these events is manageable on its own.
If several occur at the same time, they could push the market into panic.
That is the central risk of the coming winter: not one predictable shortage, but the correlation of several independent shocks.
Why Europe Has Still Not Returned to 2022
Panic-driven comparisons with 2022 may be politically convenient, but economically they are inaccurate.
At that time, Europe was structurally dependent on massive Russian pipeline flows and was effectively trying, in real time, to build a replacement for a supply system that was disappearing.
Today, that replacement exists.
Gas terminals have been built. Interconnectors have been expanded. Internal EU flow patterns have been reshaped. Imports have been diversified. Consumption is lower. Wind and solar generation is substantially higher.
On August 13, Reuters highlighted another structural trend: combined wind and solar generation in Europe is increasingly surpassing gas-fired generation in 2026, reducing the duration of periods in which gas is used intensively in the power sector. Europe’s installed wind and solar capacity has approached 750 GW.
That is why the probability of a physical collapse resembling the worst fears of 2022 is lower.
But the new system has developed a different weakness.
The old dependency was concentrated and obvious.
The new one is distributed, and therefore psychologically less visible.
Europe depends on Norway.
On U.S. LNG.
On the global shipping system.
On Hormuz.
On Asian demand.
On the reliability of nuclear generation.
On the wind.
On temperature.
On the condition of several dozen export facilities.
And on the market’s ability to fill storage even when doing so makes little commercial sense.
Europe’s Central Mistake: Mistaking a Change of Supplier for Energy Independence
The debate over Russian gas is often built around a false choice.
On one side is the argument that Europe committed economic suicide by abandoning cheap Russian fuel.
On the other is the claim that simply replacing Russian gas with U.S. and Qatari LNG is enough to eliminate the problem of dependence.
Both arguments are too simplistic.
Returning to the old model would mean restoring a strategic dependence on a single supplier that has already demonstrated its ability to turn energy into an instrument of great-power politics.
But replacing that model with LNG imports does not create energy sovereignty.
It creates a market that is more competitive and more flexible, but also more expensive and more exposed to global crises.
The true price of independence is not determined by the nationality of a gas molecule.
It is determined by how well an economy can function without that molecule at a critical moment.
That is why Europe’s main response to the crisis does not lie only in new contracts with the United States, Qatar, Algeria, or Norway.
It lies in power grids, energy storage, nuclear generation, heating modernization, industrial energy efficiency, long-term contracts, reserve mechanisms, and an electricity-market design in which a handful of expensive gas-fired power plants cannot automatically set the price for the entire system.
The war involving Iran has exposed something Europe declared solved too soon.
Dependence on Russian gas has indeed been sharply reduced.
Europe’s dependence on gas has not.
It has simply become global.
That is why the defining question for the winter of 2026–2027 is no longer this: can Russia cut off Europe’s gas?
Europe has largely found an answer to that question.
The new question is much more difficult: how much is Europe prepared to pay for gas when Germany, China, Japan, and South Korea are all competing for the same tanker, while the route from producer to buyer passes through a war zone?
If the winter is mild, Europe will most likely once again declare its energy restructuring a success.
If the winter is cold, windless, and coincides with another external shock, an uncomfortable reality will become clear: the continent has built enough terminals to receive gas, but it has not yet built a system capable of guaranteeing that the gas will be available at a price that allows European industry to remain competitive.
And that is far more serious than the percentage of gas currently sitting in storage.
In 2022, Europe feared running out of gas. In 2026, its principal risk is different: the gas will be there, but the price may prove economically destructive.