• European benchmark gas prices are nearing crisis-era levels, with the Dutch TTF front-month contract hitting €97.35/MWh, the highest since late 2022.
  • Unusually low storage, disrupted LNG supplies, and colder-weather risks are tightening the market ahead of winter.
  • Analysts warn prices could exceed €100/MWh if disruptions persist, raising costs for households and industry.

Gas Prices Approach Crisis-Era Levels

European natural gas prices are surging toward levels last seen during the 2022 energy crisis, as a combination of disrupted LNG supplies, abnormally low storage, and the threat of a cold winter strain the market. The benchmark Dutch TTF front-month contract rose to €97.35/MWh in morning trading on October 28, according to market reports, marking its highest point since late 2022. The headline figure of €100/MWh has not been confirmed in available sources, but the intraday move suggests the psychologically significant threshold is within reach.

The rally has been building for days. On October 26, the front-month contract reached €97.64/MWh, nearly 3% above the previous Friday’s close, according to DPA. Prices briefly eased on October 27 before resuming their climb, supported by ongoing Norwegian supply disruptions and depleted inventories. Renewed attacks on Saudi energy infrastructure over the weekend added to concerns about the Middle East conflict and already-disrupted shipping through the Strait of Hormuz, further unnerving traders.

A Thin Winter Buffer

The fundamental driver is Europe’s precarious storage position. The EU energy regulator ACER reported on October 27 that storage stood at 75% as of October 21—well below the five-year average for this time of year. Europe ended the previous winter with storage at just 28%, down from 34% a year earlier, and has struggled to rebuild inventories amid strong demand and limited supply.

The problem is not merely the volume of gas in storage but the rate at which it can be withdrawn. As storage sites empty, their maximum daily withdrawal capacity declines, leaving Europe vulnerable to a late-winter cold snap. Matt Drinkwater, head of European gas at Energy Aspects, warned that insufficient starting inventories leave the continent particularly exposed.

“We’re entering the heating season with a much smaller safety buffer than normal,” Drinkwater said, according to a note to clients. “If we get a sustained cold spell, we could see prices spike well above current levels.”

Missing LNG and Fierce Competition

ACER’s latest assessment paints a stark picture of Europe’s supply challenges. No significant Qatari LNG volumes reached the EU during the summer of 2026, and total EU LNG imports fell 14% year-on-year. US LNG now supplies around 30% of total EU gas needs, while Russian gas—despite ongoing phase-out efforts—still accounts for around 11%.

Hot weather and drought across southern Europe also increased gas-fired electricity generation by nearly 9% over the gas summer period, further complicating efforts to refill storage. With domestic production declining and pipeline imports limited, Europe must compete aggressively for internationally traded LNG, particularly cargoes that might otherwise go to Asia. Higher European prices help attract those supplies but transfer the shortage and affordability pressure elsewhere.

Economic and Political Repercussions

The price surge is already feeding through to the broader economy. ACER estimates that the Middle East conflict has added €18–33 billion to Europe’s gas import bill for the same quantity of gas—a substantial additional cost that will ultimately be borne by households, industry, and electricity consumers.

Greece’s wholesale electricity price averaged roughly €187.76/MWh in October, about 20% above September, according to market data, reflecting greater gas use and lower renewable generation. EU carbon allowances have also rebounded as gas prices moved above €90/MWh, incentivizing fuel switching.

The policy response is complicated by the need to balance security of supply with affordability. The EU extended its gas storage framework through the end of 2027, maintaining a 90% headline target but allowing countries to meet it between October 1 and December 1, rather than facing a single November 1 deadline. The framework also permits deviations under difficult market conditions, a recognition that rigid deadlines can force expensive purchases.

Outlook Hinges on Weather and Supply

Analysts are reluctant to offer precise price targets, given the volatility of the market. Morningstar (MORN) analyst Tancrede Fulop told CNBC in August that prices could reach €90–120/MWh in a cold winter scenario—a range that current prices are already approaching.

Goldman Sachs (GS) has warned that prices may need to exceed €100/MWh to reduce Asian demand sufficiently for Europe to manage winter inventories. That scenario assumes a gradual recovery in Gulf LNG exports; a sustained disruption would require even higher prices to balance the market.

“The market is trying to price in the risk of a cold winter and the loss of Qatari supply,” said a London-based gas trader, who asked not to be identified because he is not authorized to speak publicly. “But the truth is, we don’t know how cold it will get or when those LNG cargoes will return. The range of outcomes is unusually wide.”

Over the longer term, additional LNG capacity could ease the tightness, but timing is critical. Wood Mackenzie told CNBC that new Qatari developments are not expected to reach full capacity before the second half of 2027, limiting their usefulness for this winter.

For now, the market remains on edge. The next few weeks will be crucial as temperatures drop and storage withdrawals begin in earnest. Whether prices breach €100/MWh on a sustained basis depends on factors beyond Europe’s control—the weather, the Middle East conflict, and the global competition for LNG.

Correction: An earlier version of this article misstated the date of ACER’s storage report. It was published on October 27, not October 26.