Opinion: Southeast Asia's Procurement Desks Have Priced In a Gas Shortage That Analysts Keep Calling Temporar

# Southeast Asia's Procurement Desks Have Priced In a Gas Shortage That Analysts Keep Calling Temporary

Southeast Asia's Procurement Desks Have Priced In a Gas Shortage That Analysts Keep Calling Temporary The Sustainable Energy Association of Singapore published a survey on Thursday that found nine in ten energy professionals across Southeast Asia say geopolitical disruptions have affected their supply chains, and 40% characterize the resulting coal increase as a short-term response. Another 28% call it a mid-term bridge. The pollsters framed this as industry confidence in an eventual pivot back to cleaner fuels. Read the underlying supply arithmetic instead, and the numbers tell a different story. Start with what JKM is doing. Asian LNG settled at $23.17/MMBtu on Friday. When JKM spiked 16% in a single session on Hormuz closure fears earlier this week, Chinese spot buyers, the world's second-largest LNG demand center, sat out the rally entirely. That abstention is more revealing than the price itself. If Chinese importers, who carry the deepest knowledge of Asian supply conditions and the most operational flexibility, declined to buy at $23, they are signaling that the price is structurally elevated rather than transiently squeezed. For Vietnamese or Filipino utilities operating under regulated tariffs, a $23 JKM is not a temporary inconvenience to be weathered, it is a procurement ceiling that makes coal the only rational dispatch option for the foreseeable future. The counter-argument runs like this: new LNG liquefaction capacity coming online through 2026 and 2027, from Qatari expansions and additional U.S. trains, will eventually relieve the tightness keeping JKM elevated. The price drops, gas-to-coal switching reverses, and the survey's 40% who called the rebound temporary are vindicated. This is a credible thesis. It is also built on a supply increment that cannot arrive fast enough to change the current dispatch calculus, and it rests on a physical constraint hiding in plain sight. U.S. LNG export terminal utilization hit 94% of DOE-approved limits in March 2026, with weekly vessel departures running at 141 billion cubic feet, already near the throughput ceiling. There is no surge capacity. The terminals are full. When Southeast Asian procurement officers read that statistic, they are reading a flat supply curve, not a supply response. Future liquefaction additions help 2027 and beyond; they do not change what a Vietnamese grid operator must run next quarter. Henry Hub closing at $2.88 on Friday, down roughly 9% since the Hormuz disruption began, adds an almost perverse dimension to this. U.S. domestic gas is getting cheaper as delivered LNG grows more expensive. The spread exists because the physical pipeline between a cheap Henry Hub and an Asian buyer is a liquefaction terminal already running flat out. For any Southeast Asian grid planner, the signal that would normally indicate cheap gas is coming is entirely disconnected from what they will actually pay. The price transmission mechanism has broken in both directions. In that environment, Newcastle coal at $124.60 per tonne physical is not the reluctant backup, it is the anchor. There is a shadow supply dynamic compounding this. Sanctioned Russian LNG flowing through southern China's Beihai port gives Chinese buyers access to discounted barrels that never show up on the spot JKM market. Chinese buyers with that conduit have less incentive to compete for spot cargoes, which keeps observable JKM elevated for every other buyer in the region. A future where the Beihai route closes and Russian supply rejoins the transparent market would push JKM lower, but that scenario depends on geopolitical conditions moving in exactly the direction they are not. Vietnam, Indonesia, and the Philippines are pricing coal off a JKM that carries a structural premium they cannot access on the downside. Now add the weather. The current meteorological briefing flags El Niño approaching potentially historic strength. This is the variable the survey's respondents could not fully price. When answering questions about the coal rebound, they characterized conditions as they stood; they were not asked to model a deteriorating hydro outlook across the Mekong basin. A strong El Niño cuts reservoir levels in Vietnam, Laos, Thailand, Cambodia, and Indonesia, the same systems that provide low-cost baseload generation and have historically allowed utilities to absorb gas price spikes without fully committing to coal. Remove that hydro cushion and grid operators have no swing fuel available. They run coal not because it is cheap but because it is the only dispatchable capacity they have contracted and fueled. The SEAS survey's 40% "temporary" read was formed without that variable embedded. If the El Niño develops as current models suggest, the coal rebound's duration extends from quarters to years, and the survey's respondents will be revising their characterization long before the underlying conditions improve. The survey itself deserves a methodological note. Its respondents skew toward professionals with an institutional stake in the energy transition narrative, association members with organizational reasons to signal optimism about the temporary nature of fossil fuel rebounds. A sample returning just 6% describing the coal increase as structural may be expressing professional preference as much as operational reality. The two previous coal rebounds in Southeast Asia, 2017-2018 and 2021-2022, did eventually resolve, but each lasted 12 to 18 months and resolved only when European demand destruction freed up global LNG cargoes for Asian markets. The current disruption has no equivalent pressure on the horizon. European gas storage sits at 63.8% capacity and injecting steadily; European LNG demand is not about to collapse and release cargoes eastward. The historical pattern the optimists are implicitly citing required a demand-side relief valve that does not currently exist. The demand-destruction counter-argument, that $23/MMBtu LNG will eventually force enough industrial cutbacks to clear the market, has merit at the margins. Energy-intensive manufacturers in Vietnam and Indonesia will delay expansion or cut output before absorbing prolonged gas exposure at these prices. But power sector demand does not work this way. A grid operator cannot destroy demand; it can only fail to serve it or run whatever generation it has contracted. In Southeast Asia's rapidly growing electricity markets, where peak demand increases roughly 3% annually and blackouts carry political consequences, the practical alternative to burning coal is not switching to gas, it is keeping the lights on with what is available. Coal is what is available. The 68% of survey respondents who described the coal rebound as temporary or a bridge measure may be expressing a genuine preference about where they want the region's energy mix to go. They may be less accurate about where supply conditions are forcing it to stay.