On Monday, October 26, benchmark European natural gas futures prices briefly broke through €97 per megawatt-hour, reaching that level for the first time since 2022. The market is simultaneously focused on the potential for increased heating demand driven by cooler temperatures in the coming days, and the potential disruptions to global liquefied natural gas flows from the ongoing conflict in the Middle East. The Dutch TTF near-month contract rose as much as 3.5% in early trading, before settling around €96.88 per megawatt-hour during Amsterdam trading hours, up 3.2% from the previous trading day. The price rebound, coupled with seasonally low inventory levels, means the European energy market faces a reality of narrowing supply buffers ahead of the peak demand season.

Benchmark futures rebound and weather-driven demand expectations

The rise in the Dutch TTF near-month contract continued last week's momentum, with trading focus on the combined effects of temperature changes and global supply tightness. Weather forecasts indicate that temperatures will drop across most of continental Europe in the coming days, with some areas in Northern Europe remaining mild, but overall heating demand expectations have been revised upwards. This demand rebound coincides with a tight global natural gas supply, potentially intensifying spot competition between European and Asian buyers. Since the energy supply adjustment in 2022, liquefied natural gas (LNG) has become an important supplementary supply channel for Europe, but its flow is highly flexible and susceptible to shipping conditions, production facility operations, and regional bidding. Current price levels are still well below the peak of the previous energy shortage, but the short-term rebound has already triggered a correlation in some electricity forward contracts.

Underground inventories are at record seasonal lows.

EU underground gas storage is currently around 75% full, the lowest level for this time of year since 2009, while German storage is only slightly above 61%. This level is significantly lower than the five-year average and also lower than the same period last year. The role of storage as a buffer for winter supply is therefore even more prominent: if temperatures remain below expectations or imports are disrupted, matching the rate of extraction with the remaining extractable supply will become more difficult. International Energy Agency chief Fatih Birol recently pointed out that Europe is entering winter with storage levels far below historical averages. If severe cold weather occurs, natural gas prices could face further downward pressure, and European buyers will be in direct competition with Asian buyers for liquefied natural gas. The low storage levels are not due to a single factor, but rather a result of the combined effects of increased electricity consumption for air conditioning due to high summer temperatures, continued competition from Asian spot markets, and partial supply disruptions from the Middle East.

The ongoing impact of Middle East conflicts on liquefied natural gas flows

The ongoing conflict in the Middle East has not quickly dissipated market expectations of supply disruptions in the Persian Gulf. Iran is reportedly preparing for possible further military action and assessing its options across the Middle East. Liquefied natural gas (LNG) has become a key supplement to European energy supplies since 2022, but its flow is highly dependent on unimpeded shipping and stable production facilities. European LNG imports have been lower than the same period last year since October, a period typically characterized by seasonal increases. The anticipated supply disruptions, coupled with supportive Asian demand, mean that Europe faces competition for supplies as it enters its peak demand season. Global supply tightness means that any regional disruptions could quickly transmit to European benchmark prices, thereby impacting electricity and industrial energy costs.

Electricity market linkages and potential pressures on economic activity

The rebound in natural gas prices has driven French near-month electricity futures above €200 per megawatt-hour for the first time since January 2023. Electricity prices are highly sensitive to natural gas costs, especially given fluctuations in wind and nuclear power output; rising marginal generation costs are directly reflected in forward contracts. While the price rebound is still below historical peaks, it carries the risk of pushing up inflation and dampening economic activity. Rising heating costs for industrial and residential users could impact overall demand through corporate profits and consumer spending. Current market pricing reflects more the combined effects of narrowing supply buffers and geopolitical disturbances than a single weather event. The European energy system's reliance on external liquefied natural gas, coupled with low inventories, makes prices more sensitive to any supply surprises.

Frequently Asked Questions

Question 1: What are the main drivers behind the recent rebound in European natural gas prices? Answer: The price rebound is mainly due to the combined effect of upward revisions to winter heating demand expectations and tight global supply. The expectation of colder temperatures and the disruption to liquefied natural gas (LNG) flows caused by the Middle East conflict coexist, while European inventories are at their lowest level for this time of year since 2009, making the market more sensitive to pricing of supply buffers. Question 2: What do current inventory levels mean for winter supply? Answer: EU inventories are around 75%, and German inventories are around 61%, significantly lower than historical averages and the five-year average. The buffering effect of inventories is therefore weakened. If sustained low temperatures or import disruptions occur, matching extraction capacity with demand will become more difficult, and prices will become more sensitive to unexpected supply events. Question 3: How do changes in natural gas prices affect the electricity market? Answer: Natural gas is one of the sources of marginal costs in the electricity market. After the rise in the Dutch TTF near-month contract, French near-month electricity futures have broken through €200 per megawatt-hour. Price linkage enters the forward pricing of electricity through generation costs and may further affect industrial electricity consumption and residential energy expenditures.