EU must find 1.3 LNG tankers daily

Europe is going into the summer refill season with its gas cupboards lighter than usual. EU storage was roughly 42% full in early June, about 14 percentage points below the five-year seasonal average and well short of the 51% recorded a year earlier (AGSI/GIE, WBJ).

That matters because the winter bill is being written now. Europe has to rebuild storage while competing for LNG, liquefied natural gas shipped by tanker, in a global market tightened by Middle East disruption, tougher Russian sanctions and strong Asian demand. The cost will not fall evenly. It will move through state budgets, energy-intensive industry and, in some countries, household bills.

The carry trade that isn't working

Gas storage normally works on a simple seasonal trade. Companies buy in spring and summer, pay to store the gas, and sell it in winter when prices are higher. The gap between summer and winter prices, known as the spread, is meant to cover the storage cost and leave a margin.

When that spread is too narrow, the incentive disappears. Companies wait. That is the problem now.

ICIS estimates that, if current slow injection rates continue, Europe would reach only about 73% by November. Getting to 90%, the legal target under the EU's storage regulation (EUR-Lex), would require injections to rise by roughly 4 bcm per month. In practical terms, that means about 1.3 extra LNG cargoes every day.

Brussels has already softened the edges of the rule. The European Commission says the updated regulation gives member states a two-month window, from October to December, to meet the 90% target. Officials have also pointed repeatedly to 80% as enough for winter security. That figure is less a formal comfort blanket than a practical threshold, intended to avoid the kind of panic buying that sent prices to record levels in 2022.

Squeezed from both sides

Even reaching 80% cheaply is becoming harder. The IEA estimates that the Middle East conflict has taken roughly 120 bcm off global LNG supply through 2030, as damaged export infrastructure and shipping disruption delay new capacity (Energy Connects, Baltic Exchange).

At the same time, Europe is closing off the Russian fallback. The EU's Russian gas phase-out law banned short-term Russian LNG contracts from 25 April 2026, with pipeline contracts following in June and all long-term Russian gas due to end by late 2027 (S&P Global). That removes a politically toxic but commercially useful option: using Russian molecules as a quick patch when storage falls short.

The market mechanism is blunt. When Asian buyers are willing to pay more for flexible LNG cargoes, Europe has to lift the Dutch TTF benchmark, the trading hub that sets European wholesale gas prices, to pull tankers west. TTF was trading around €50/MWh in early June (Berliner Zeitung). Spain's MIBGAS day-ahead price was close behind at €48.80/MWh (MIBGAS). ACER, the EU energy regulator, warned that filling storage to 90% would require roughly 13% more LNG imports than in 2025 (MondoVisione).

Who pays depends on where you live

The EU average hides very different national positions. The Netherlands had only 16.1% storage on 1 June (Energievergelijk). Spain's regasification plants were 72% full (Europa Press). Germany was at 34-35%, roughly 20 points below its own seasonal norm (NDR).

Governments are intervening, but not with the same instruments. Germany abolished its storage levy on 1 January 2026 and moved the cost on to the federal budget, so taxpayers rather than gas customers now underwrite storage security (FGS). The Netherlands has a €20bn loan facility for state-backed EBN to step in when commercial filling stalls (DutchNews). Hungary's fixed-price system leaves state-owned MVM absorbing higher import costs until the government changes course, a fiscal buffer that works until it runs out of room (HVG).

Industry feels the price first. BASF's chief executive warned that European gas prices are now structurally set by global LNG markets rather than pipeline contracts (Zeit). Households feel it later, through contract renewals and national policy choices. In Spain, the route is through electricity: when gas-fired plants set the marginal power price, meaning the cost of the final unit needed to meet demand, wholesale gas prices feed straight into bills. Spain's regulated PVPC electricity tariff rose 15% in May (OCU).

The winners are LNG suppliers, flexible cargo owners and storage operators: anyone able to sell into Europe's need for security. The losers are industrial users competing globally and governments trying to cover the gap between market prices and what voters will tolerate. Europe can probably avoid a physical shortage this winter. The harder question is the price of that safety, and whether poorer member states can afford to buy it on the same terms as Germany and the Netherlands.