Alaska LNG's production costs could run more than double those of most US Gulf Coast LNG export projects, a Reuters analysis has found, raising the question of whether the $44-55 billion project can attract the financing it needs to reach a final investment decision.

The cost estimate comes from Glenfarne Group, the majority owner and developer of the proposed project. The figure covers the full scope of the development: a gas pipeline running from Alaska's North Slope across the state to a liquefaction and export terminal on the southern coast.

This week, the Trump Administration touted a $50-billion investment commitment from South Korea for the proposed Alaska LNG project. Seoul has disputed that characterization. The administration has championed the project as a centerpiece of its energy export agenda, but the White House does not control the commercial arithmetic that will determine whether the project gets built.

The core issue is delivery cost. Most US Gulf Coast LNG projects feed on gas from nearby shale basins — the Permian, Haynesville, and Eagle Ford — with established pipeline networks and brownfield expansion options at existing terminals. Alaska LNG must move gas roughly 800 miles from the North Slope, through terrain that drives both capital and operating costs well above what Louisiana and Texas competitors face.

That gap puts the project's economics in the hands of Asian buyers. The Reuters analysis frames the investment case around how much premium Northeast Asian importers will pay for energy security — a diversified supply source outside the Gulf of Mexico hurricane corridor and outside the Strait of Hormuz shipping lane.

Buyers in Japan and South Korea have historically paid premiums for supply diversity and long-term contracting certainty. Whether that willingness extends to covering a cost base twice that of competing US cargoes is the unanswered question hanging over the project.

The South Korean commitment illustrates the uncertainty. The Trump Administration's $50-billion figure, if fully realized, would approach the entire estimated project cost. Seoul's dispute over the announcement suggests the number does not represent a firm, sanctioned offtake and investment package. Long-term SPAs with creditworthy Asian utilities — not political announcements — remain the prerequisite for Glenfarne to sanction construction.

For US gas producers, the stakes are concrete. Alaska LNG would open a second export corridor for North American gas and monetize North Slope reserves that currently lack a route to market. Gulf Coast developers, meanwhile, would see a new competitor for Asian demand, albeit one shipping from a longer distance to Northeast Asia than cargoes transiting the Panama Canal.

The project's timing also matters for the broader LNG supply picture. A wave of Gulf Coast capacity — Plaquemines, Corpus Christi Stage 3, Golden Pass — is ramping through the middle of this decade. If Alaska LNG reaches FID and takes roughly five years to build, its cargoes would land in an early-2030s market where buyers will have had time to test whether energy-security premiums justify premium-priced contracts.

Glenfarne, which also developed the Magnolia and Texas LNG projects, has positioned Alaska LNG as a strategic export route rather than a purely merchant play. The Reuters analysis suggests that positioning is not optional — it is the only path to commercial viability at the project's cost structure.

The watch items are clear. Watch for South Korea to clarify the substance of its commitment — whether the disputed $50 billion translates into binding offtake agreements. Watch for additional Asian SPAs, which Glenfarne needs to close the financing gap between strategic interest and bankable revenue. And watch for the FID window: every year of delay pushes Alaska LNG's startup deeper into a decade when competing US volumes will already be flowing to the same customers the project is counting on to pay its premium.