JP Morgan Says ‘$10 Diesel by December’

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When the Strait of Hormuz turns unreliable, Asia pays first and most: a chokepoint shock converts geopolitical risk into immediate cash costs, pushing spot LNG and oil benchmarks sharply higher and straining the budgets of import‑dependent economies long before the rest of the world feels the full pinch.

At a Glance

Asian spot LNG prices more than doubled into the mid‑$20s per mmBtu after the Iran war escalated, the highest since late 2022.
Roughly a fifth of global LNG and the bulk of Persian Gulf oil and gas shipments transit Hormuz; close to 90% of those exports head to Asia, concentrating the shock.
Disruptions and infrastructure damage to Qatar’s Ras Laffan tightened supply further, forcing Asian buyers into expensive spot tenders.
Result: higher utility costs, tougher power‑sector fuel switching, and macro headwinds for Asia’s emerging markets.

Why Asia’s energy bill spikes first in a Gulf crisis

Energy markets punish proximity to chokepoints. The Strait of Hormuz is the world’s most consequential energy corridor for seaborne oil and LNG; when conflict jeopardizes it, the buyers most reliant on that route face the steepest, fastest price repricing. In 2025, almost 90% of exports through Hormuz were destined for Asia, and LNG delivered via the strait accounted for roughly 27% of Asia’s total LNG imports—versus about 7% for Europe—so the regional exposure is structural, not incidental. Layer on top the simple arithmetic of volume: around 20% of global LNG typically moves through Hormuz, overwhelmingly toward Asian markets. That geometry turns a regional security event into an Asian energy shock within weeks, not quarters.

The mechanism is brutally simple. Long‑term contracts cover much of Asia’s LNG needs, but when pipeline alternatives are sparse and contracted Qatari cargoes are delayed or curtailed, utilities and state buyers must procure prompt deliveries on the spot market. The marginal cargo sets the price; when anxiety collides with scarcity, that marginal price jumps. Hence the observed doubling of North Asia spot LNG to roughly $25–$26 per mmBtu during the conflict’s escalatory phases, levels last seen during the post‑Ukraine invasion scramble.

How the current shock built: supply, shipping, and Ras Laffan

Three reinforcing constraints explain the intensity of this episode. First, shipping risk raises effective delivered costs. Threats to transit amplify insurance premia, extend voyage times, and reduce fleet productivity; each day added or ship idled tightens prompt availability. Second, LNG flows have proven more fragile than oil flows under Hormuz stress—volumes through the corridor can crater, leaving buyers to compete for Atlantic Basin cargoes or Australian volumes already spoken for by Northeast Asia and China’s portfolio players. Third, this conflict’s physical damage matters: consultancies report that harm to parts of Qatar’s Ras Laffan liquefaction complex, in combination with blocked or throttled transits, sidelined around 12.8 million tons per year for years, not weeks—an enduring dent in expected supply growth.

The net effect is fewer contracted arrivals and more spot exposure. Developing Asian markets—India, Bangladesh, Pakistan, Thailand, Vietnam—are acutely sensitive. They plan power systems around affordable molecules, but when contracted Qatari liftings “dry up,” they must either pay up for prompt LNG or revert to oil and coal. Bloomberg estimates put the incremental gas bill shock to these markets in the multi‑billion‑dollar range as they chase replacement cargoes in a thin market. That is not an abstract ledger entry; it flows into power tariffs, fiscal subsidies, and current‑account balances within a single cooling or monsoon season.

What the price surge tells us—and what it doesn’t

Prices are the market’s scoreboard, and they have registered stress. North Asia spot LNG more than doubled into the mid‑$20s per mmBtu, touching the highest marks since 2022 as hostilities escalated and logistics uncertainty compounded the supply hit. That spike arrived alongside firmer crude benchmarks as the oil complex priced in both disruption risk and the secondary effects of gas‑to‑oil switching in power generation and industry. None of this implies a uniform, indefinite shortage. Portfolio suppliers reoptimize; Europe yields some flexibility when storages are adequate; and seasonal shoulder periods can blunt demand. But the floor lifted: even when prompt prices eased intermittently, they stabilized well above pre‑conflict levels, reflecting an area‑under‑the‑curve loss of supply and higher perceived risk premia.

In other words, volatility is now the baseline. The market’s capacity to absorb shocks—floating storage, spare shipping, swing supply—erodes when a corridor that routinely moves a fifth of global LNG is contested. Asia’s vulnerability is a function of concentration: China, India, Japan, and South Korea account for the dominant share of oil and LNG that passes Hormuz; Japan and South Korea in particular import more than four‑fifths of their energy, leaving little room to hedge with domestic production.

Winners, losers, and the uneasy calculus for policymakers

There are no free lunches in fuel substitution. When LNG prices jump, power systems reach for oil or coal if they can—raising crude demand and emissions, while exposing refiners and utilities to their own supply frictions. Some incumbent producers benefit from elevated benchmark prices, and Atlantic LNG sellers with optionality can capture windfall margins redirecting cargoes to the Pacific basin. But for Asian governments, the menu is unappetizing: absorb higher import costs via subsidies and pressure public finances, pass them through to consumers and stoke inflation, or curtail demand and risk industrial output. For lower‑income buyers already scarred by past spikes, the case for LNG as a “bridge fuel” weakens when security‑of‑supply looks contingent on a single strait.

This is why consultancies and system operators model demand destruction alongside substitution. Wood Mackenzie, for example, frames scenarios where South and Northeast Asia trim several million tonnes of LNG demand across a single quarter if Hormuz disruptions persist—less because factories need less energy, more because they cannot reliably secure molecules at tolerable prices. That is rationing by price, and it leaves scars in the form of deferred investment and re‑shored energy‑intensive production elsewhere.

What resilience actually looks like from here

There is no silver bullet, but there is a playbook. First, diversify molecules and routes: accelerate regas access to Atlantic Basin supply, expand floating storage and regasification units to create optionality, and support new long‑term contracts that are less corridor‑dependent. Second, harden the logistics chain: more ice‑class and Q‑Flex‑capable ships are not helpful here, but additional hulls and better charter flexibility improve shock absorption when voyages lengthen. Third, reduce the call on spot: demand‑side flexibility—industrial interruptible contracts, peak‑shaving with LPG or fuel oil where compatible, and deeper electricity market reform—can shave the most punitive price hours. Fourth, lean into regional coordination: shared strategic stocks in LNG are nascent, but gas‑storage policy, cross‑border power interconnectors, and data transparency reduce panic bidding.

Finally, treat risk premia as a feature to manage, not a bug to wish away. If a fifth of global LNG rides through a single chokepoint and nearly nine‑tenths of it serves Asia, then insurance, convoying, and naval security are energy policy by other means. Budget for that. Markets will still convulse on headlines, but a system designed to live with chokepoint risk—contractually, logistically, diplomatically—will convert those convulsions from crisis to cost line. That is the difference between an energy shock that derails growth and one that dents margins but leaves the lights on.

Bottom line

The evidence is unambiguous: the Iran war’s disruption to the Strait of Hormuz and damage to Qatari LNG capacity tightened Asia’s gas balance, forcing buyers onto the spot market and driving prices to their highest levels since 2022. Asia is structurally exposed because it sits downstream of the chokepoint and depends on it disproportionately. Until trade routes normalize and new supply arrives, volatility and elevated premia are not anomalies to be arbitraged away; they are the cost of concentration—and the bill is arriving first in Asia’s mailbox.