LNG flows from the Persian Gulf remain more than 75% below their levels of February 28, and the shortfall is now redrawing fuel economics on both sides of the Suez. With heating demand rising ahead of winter, buyers are weighing a coal price roughly 80% below LNG — a spread that regulation, not the market, was supposed to close.

What do the numbers show?

The European benchmark for November natural gas delivery is trading above €81 per MWh. In Asia, spot LNG prices have moved above European levels, pulling flexible cargoes eastward and leaving European buyers competing for a thinner residual supply.

The arithmetic is blunt:

• Gulf LNG flows: still >75% below pre-February 28 levels
• European November gas benchmark: >€81/MWh
• Asian spot LNG: trading at a premium to Europe, redirecting cargoes east
• Coal: roughly 80% cheaper than LNG at current pricing

For gas-fired generators and industrial buyers, that spread is no longer marginal. It is large enough to force fuel switching wherever the permit regime allows it.

Where does coal fit in?

Coal has carried the heaviest regulatory burden of any fuel — the target of most climate-related rulemaking on the grounds that it emits the most carbon dioxide, alongside pollutant gases and particulate matter. That regulatory logic assumed coal would price itself out of the merit order as gas stayed cheap and abundant.

The current market inverts that assumption. With Gulf LNG still off the water and winter load approaching, coal's 80% discount to LNG makes it the default swing fuel for any operator with dual-firing capability or an existing coal unit still on the licence. The regulatory framework has not changed; the economics underneath it have.

The takeaway for plant operators: fuel choice this winter will be decided by the cargo map, not by the rulebook alone.

What does the cargo redirection mean for Europe?

Asian spot LNG clearing above European prices matters because it moves the marginal cargo. Portfolio sellers route volumes to the highest netback, and that is currently Asia. European utilities therefore face a double squeeze: a Gulf base-load supply still down more than three-quarters, and spot cargoes that now land elsewhere first.

At €81/MWh, the November contract already reflects that tension. Every additional euro widens the coal-to-gas switching band and increases the probability that coal-fired units run harder through the heating season than climate policy anticipated.

What should practitioners watch?

Three variables will set the trajectory from here. First, the pace at which Gulf flows recover toward pre-February 28 volumes — until that number moves materially, the global LNG balance stays structurally short. Second, the Asia-Europe spot spread: as long as Asia holds the premium, Europe buys last. Third, winter heating demand itself, which converts a tight paper market into a physical shortage.

The price commentary in this piece is market analysis to attribute to current trading, not a forecast — but the supply gap is a measured fact, and it has not closed.

The watch item is whether Gulf LNG flows recover before peak winter demand arrives; if they do not, coal runs, whatever the regulations say.

By James Calloway