Australia's Gas Producers Hold Domestic Prices in Check as Iran War Rattles Global LNG
Unlike during the Ukraine war three years ago, Australian exporters are avoiding price increases on domestic gas even as global LNG markets seize up.
Australia's major gas exporters have held domestic prices in check through the Iran-triggered LNG disruption, a deliberate reversal from their conduct during the Ukraine war three years earlier when producers extracted elevated domestic rates that drew regulatory scrutiny from the Australian Energy Regulator.8
The physical backdrop this time is, in some respects, more severe. The last cargoes of liquefied natural gas from the Gulf — a region accounting for roughly a fifth of global production — departed before American and Israeli strikes on Iran, leaving destination terminals to draw down inventory. The resulting supply squeeze pushed global gas benchmarks sharply higher, with ICE Endex TTF front-month gas reaching levels that analysts at Oxford Economics warned could lift EU inflation from its recent 2% toward 4% or above. JKM, the Northeast Asian spot LNG benchmark, firmed on renewed buying interest as Asian buyers competed for available non-Gulf cargoes.6,3,4
Australian exporters had reason to exercise restraint this time. A mandatory domestic gas code was still being finalised when the Iran crisis hit, leaving producers in what one report described as a heightened state of fear about repeating the 2022 episode. The exporters appear to have calculated that the political and regulatory cost of a second round of domestic price gouging exceeds whatever margin they might gain.8
The consequence for Australian households has been notable. While Britain confronted electricity bill shocks — the United Kingdom sources about 24% of its power from wind but gas still sets the marginal price — Australia's accelerating rollout of renewables and battery storage provided a second layer of insulation. Renewable energy and batteries are actively decoupling Australia's electricity prices from the global gas signal, according to a June (2026-06-07) analysis that tracked the divergence between Australian and European power prices during the Iran disruption.1,7
Europe carries the heavier burden of the supply disruption. EU gas storage stood at 31.1% full as of February 20 (2026-02-20) per AGSI+ data, roughly 35 percentage points below the five-year average at that calendar point. Equinor, Europe's largest gas supplier, subsequently warned that the continent would struggle to refill storage to the targeted 80% by winter given the pace of the drawdown.5,2
The continent has looked to alternative LNG sources, but the arithmetic is difficult. LNG accounts for around 25% of Europe's total gas supply, according to Stifel analyst Chris Wheaton, meaning even a partial Gulf disruption creates a gap that spot market procurement can only partially fill. The European Commission said the continent spent an additional €6bn on fossil fuel imports between early March and mid-May (2026-05), at prices Ursula von der Leyen described as the price we pay for our dependency.4,3
Indonesia and other Asia-Pacific producers have absorbed some incremental demand for non-Gulf LNG, but their capacity to ramp supply quickly is constrained by project lead times. JKM settled at $15.52 per MMBtu as of Friday's close (2026-06-27), reflecting ongoing tightness even after some moderation from the initial spike. ICE Endex TTF front-month gas was trading at €40.84 at the same point, a level that in normal times would incentivise heavy gas-to-coal switching in European power markets.4,5
Coal has already recovered some of that ground. With Gulf LNG unavailable, utilities in fuel-flexible markets have returned to coal burning. In Italy, gas sets the marginal electricity price in 89% of hours so far in 2026 according to Ember, and Newcastle physical thermal coal at approximately $126 per tonne as of Friday's close (2026-06-27) represents a financially viable alternative for buyers with that flexibility.6,3
Australia, meanwhile, still transmits the global disruption through liquid fuel markets. The country imports roughly 80% of its petrol, diesel and jet fuel requirements, and ICE Brent crude front-month settled at $73.08 as of Friday's close (2026-06-27) — down from earlier highs that accompanied peak Hormuz risk pricing but still elevated against the pre-conflict baseline.1,2
The near-term signal for domestic gas will be how the code finalisation lands. If mandatory obligations include binding price caps with enforcement teeth, this cycle's restraint may establish a durable precedent. If the framework emerges with softer language, the question becomes whether producers calculate that a third confrontation with Australian regulators — in the middle of a prolonged global crisis, with coal already recovering and public attention fixed on energy bills — is a risk worth taking.8