On Monday, May 25th, in early European trading, the European natural gas market repriced geopolitical risks. The Dutch TTF near-month contract fell to around €46/MWh, a daily drop of approximately 5.5%. This decline was not due to a significant weakening of European demand, but rather to the cooling of supply risk premiums caused by expectations of renewed negotiations between the US and Iran regarding the resumption of passage through the Strait of Hormuz. Meanwhile, the EU's gas storage rate was around 38%, lower than the five-year average of around 52% for the same period, making the price decline difficult to simply equate with a loosening of fundamentals.

Risk premiums have been given back, but prices have not returned to their comfort zone.

The immediate trigger for this round of TTF declines was the market's increased bet on the probability of the Hormuz Channel reopening. This channel's impact on energy trade extends beyond crude oil; it also affects approximately one-fifth of seaborne liquefied natural gas (LNG) flows. Previous restrictions on passage had heightened concerns in Europe about the stability of LNG arrivals, with prices incorporating significant premiums for transportation, insurance, and alternative sourcing.

However, judging from prices around €46/MWh, European natural gas remains in a relatively high volatility range. The price decline reflects a tail risk discount rather than a full recovery of the supply chain. If negotiations are ultimately successful, spot market sentiment may continue to ease; however, if implementation details fluctuate, shipping schedules, insurance premiums, and capacity arrangements could still cause the risk premium to re-enter the curve.

Low inventory levels weaken Europe's ability to pressure prices.

The most vulnerable segment of the European market remains gas storage. The EU's gas storage rate is approximately 38%, significantly lower than the five-year average of around 52%; in late April, the storage rate was still around 31%, a low level for the same period in recent years. In other words, the current replenishment pace is insufficient to support a stable market expectation for a safe margin during the winter.

Low inventory levels can alter the meaning of price declines. Normally, lower upstream prices help stimulate gas injection demand; however, if Asian LNG prices are relatively more attractive, even with price drops, Europe may not be able to attract sufficient supply. ING analysts recently pointed out that declining TTF prices are detrimental to Europe's ability to attract LNG, as the spread between Northeast Asian LNG spot prices and TTF prices is widening.

Competition in liquefied natural gas has once again become the core of pricing.

The European gas market has shifted from being dominated by pipeline supply to relying more on marginal pricing of liquefied natural gas (LNG). As a result, European prices are not only affected by local temperatures, inventory levels, and industrial demand, but also by competing with Asian buyers for the same flexible supply. When TTF (Total Liquidity Term) prices fall rapidly while Asian spot prices remain resilient, the flow of goods naturally skews towards markets with higher returns.

This implies an implicit price floor in Europe: a balance must be maintained between inventory replenishment pressures and the attractiveness of cross-regional supplies. If TTF falls too quickly, gas injection costs decrease, but port arrivals reduce resources; if TTF remains high, Europe can enhance its purchasing competitiveness, but this will compress industrial profits and increase power system costs. The current core contradiction in the market is that prices need to simultaneously accomplish two tasks: reduce risk premiums without weakening restocking capacity.

The curve structure is more noteworthy than the spot price decline.

One of the key topics of recent market discussion is the unusual structure of summer prices being higher than winter prices, which is weakening the incentive for commercial gas injection. Energy market participants have previously warned that if the restrictions imposed during the Hormuz conflict continue for 1 to 3 months, European gas storage could become even tighter; they also stated that if the conflict ends, Europe could still push its storage rate to approximately 75%, but if the disruption persists, the pressure of shortages will intensify.

This indicates that the current price decline does not signify the disappearance of restocking pressure. If the summer-winter price difference cannot be corrected, there will be insufficient commercial incentive to hold inventory, and gas storage will rely more on policy constraints and risk management needs. In Europe, the power, industrial, and residential heating sectors will continue to amplify the elasticity of natural gas demand in winter. If summer restocking is insufficient, winter prices may again rely on demand disruption to achieve equilibrium.

Frequently Asked Questions

Question 1: Does the decline in TTF mean that the supply and demand of natural gas in Europe has eased?
A: That's not the correct interpretation. This round of price declines is mainly due to the erosion of risk premiums brought about by the Hormuz accession negotiations, while the EU's gas storage rate remains below the seasonal average, and the winter safety margin has not yet been restored.

Question 2: Why might a price drop actually hinder European restocking?
A: Europe needs to compete with Asia for liquefied natural gas (LNG). If TTF prices fall more than Asian prices, supplies will flow to regions with higher returns, potentially limiting the speed of European restocking.

Question 3: What variables should the market pay attention to going forward?
A: The key factors are the progress of negotiations, the flow of LNG cargoes, changes in the summer-winter price spread, and the pace of EU gas injection. Daily price fluctuations are of limited importance; the inventory curve is a better indicator of winter risks.