Tanker Fleet Caps LNG Plant at 40% of Nameplate Despite Asian Price Premium
Rystad calculates shipping constraints limit one facility to 5.2-5.4 million tonnes annually, far short of its 13.2 million-tonne two-train nameplate capacity.
An LNG facility with two operational production trains and combined nameplate capacity of 13.2 million tonnes per year is exporting no more than 5.2 million to 5.4 million tonnes annually because its current tanker fleet cannot move more volume, Rystad Energy estimated — a utilization rate of roughly 40% at a time when buyers are paying elevated spot prices to secure cargoes.6
JKM, the Asian LNG spot benchmark, stood at $24.09 per MMBtu on Friday (2026-09-04), supported in part by disruption to Middle East LNG flows through the Strait of Hormuz. Asia absorbs nearly 90% of LNG exported by Qatar and the UAE, S&P Global Platts noted, meaning any Hormuz constraint compresses supply available to Asian buyers and intensifies competition for flexible spot cargoes elsewhere.6
Rystad's figures suggest the plant's trains are capable of producing more than its tanker fleet can ship. Each extra tonne moved toward nameplate would translate into spot market revenue at current JKM levels. Roughly 7.8 million to 8 million tonnes of annual export potential sits unshipped.6
Shell said in early July (2026-07-01) that if Hormuz shipping normalizes, traded LNG volumes for 2026 could still match 2025 levels — a relatively optimistic call given the scale of disruption. Shell's own LNG sales rose 11% last year to 72.9 million metric tonnes, according to its annual report. The company's 2026 forecast was contingent on normalization of strait transits over the summer.3
A Hormuz normalization could loosen freight supply indirectly. Middle East cargoes returning through the strait would free vessels currently rerouting around the Arabian Peninsula, in theory cutting both transit time and charter costs for cargoes moving toward Asian buyers. Whether that pressure has eased enough to help fleet-constrained plants source additional tonnage is unclear from available data.6
The broader supply outlook points toward relief, but not soon. Shell's LNG Outlook 2026 projects around 180 million tonnes of new annual LNG supply entering the market by 2030. But new liquefaction capacity added without matching tanker commitments would reproduce the same constraint at larger scale.2
U.S. gas output is growing fast enough to support the next wave of export projects. EIA data published in May (2026-05-21) showed Lower 48 marketed production averaged 117.2 Bcf/d in the first quarter of 2026, 4% above the same period last year, with Permian Basin output forecast at 29.2 Bcf/d for the full year, 6% above 2025. NYMEX Henry Hub front-month gas was flat at $2.94 per MMBtu on Friday (2026-09-04), cheap feedstock that keeps U.S. LNG economically competitive in Asian markets regardless of freight costs.1
Nigeria is pursuing expansion on a different timeline. NLNG's planned Train 7 would lift output from 22 million to 30 million tonnes annually, a 35% increase, with NLNG management noting in late July (2026-07-28) that Australia built 88 million tonnes of export capacity from roughly 120 trillion cubic feet of proven reserves while Nigeria holds approximately 209 trillion cubic feet yet exports far less.5
Shell's LNG Outlook 2026 puts global demand at nearly 700 million tonnes per year by 2050, 65% above 2025 levels, underwriting the long case for capacity investment. But for the plant Rystad analyzed, the near-term question is simpler: whether its operator has additional tonnage under long-term contract or is relying on a spot freight market already squeezed by the Hormuz disruption. That distinction sets the pace at which idle production capacity becomes actual export revenue.4,6