Alaska LNG Project Expands Buyer Talks With FID Approaching and U.S. Export Capacity Set to Double
Alaska LNG's push for new offtake agreements comes as planned U.S. projects could add 14 Bcf/d of export capacity by 2029, reshaping global LNG supply.
Alaska's proposed $55 billion LNG export project is in active talks with additional buyers ahead of a final investment decision, oilprice.com reported on August 11 (2026-08-11), as developers push to secure the long-term offtake agreements that any project of this scale requires before construction can begin.5
U.S. projects in the pipeline — across facilities including Plaquemines LNG, Golden Pass, Corpus Christi, and others — could collectively add as much as 14 billion cubic feet per day of export capacity between 2025 and 2029, effectively doubling current U.S. export capacity, oilprice.com reported. Alaska LNG wants a slice of that demand wave, not to arrive after it has already been claimed by Gulf Coast rivals with shorter build timelines.5
The project's geographic pitch is straightforward. Alaska sits roughly one-third of the distance to Japan compared to Gulf Coast terminals, according to project proponents cited in recent coverage, and the route to East Asia avoids the Panama Canal, the Suez Canal, and — critically given current conditions — the Strait of Hormuz.5
That last point carries immediate commercial weight. The Hormuz closure, which began on February 28 (2026-02-28), has disrupted more than 10 billion cubic feet per day of global LNG supply, or approximately 20% of the total, primarily from Qatar's Ras Laffan export facility, according to EIA data. QatarEnergy declared force majeure on March 4 (2026-03-04), forcing Asian buyers who import more than 80% of Qatari gas to compete for spot cargoes on global markets to replace lost contract volumes.1
Asian LNG spot prices have responded. JKM stood at $21.24 per MMBtu on August 13 (2026-08-13). ICE Endex TTF front-month gas was trading at €61.03 per MWh at 08:15 UTC on August 13 (2026-08-13). EIA data showed TTF futures had already surged to $14.80 per MMBtu for the week ending April 24 (2026-04-24), 35% above pre-closure levels, as European buyers scrambled alongside Asian competitors for available spot supply.1
U.S. domestic prices have moved in the opposite direction. NYMEX Henry Hub front-month gas was at $2.79 per MMBtu on August 13 (2026-08-13) — down roughly 9% since the February 28 (2026-02-28) Hormuz closure, according to EIA analysis, reflecting limited near-term export expansion capacity and ample domestic storage. That spread between U.S. production costs and international delivery prices is the commercial logic underpinning every new U.S. liquefaction project seeking buyers right now.1
American terminals are already running hard. Export terminal utilization reached 94% of maximum DOE-approved export levels in March (2026-03), EIA's Short-Term Energy Outlook showed, up from 91% in February (2026-02) when exports ran at an estimated 17.3 Bcf/d. The EIA's quarterly projections show gross LNG exports averaging 16.7 Bcf/d in the third quarter of 2026, rising to 18.0 Bcf/d in the fourth quarter, and reaching 18.7 Bcf/d in the first quarter of 2027.1,3
One milestone arrived in April. On April 22 (2026-04-22), Golden Pass LNG shipped its first cargo, becoming the tenth U.S. liquefaction terminal to enter service — though EIA counts it as the ninth under a methodology that treats co-located Corpus Christi and Corpus Christi Liquefaction Stage 3 as a single terminal, reflecting different train technologies on the same site.2
Daniel Yergin, speaking in July 2026 (2026-07), said U.S. LNG growth was exceeding all expectations. That assessment predated the latest Alaska buyer discussions but frames the appetite: demand for long-term U.S. supply agreements is high, and sellers know it.3
Alaska LNG's challenge is timeline. Gulf Coast projects can point to operating or near-operating terminals. Alaska is still pre-FID, asking buyers to commit capital to a project in a state that has seen LNG ambitions stall before. The route advantages are real. But the construction risk over a Sabine Pass or a Corpus Christi is also real, and buyers weighing 20-year contracts will price that gap.5
The Hormuz disruption has made the diversification argument easier to advance in Tokyo, Seoul, and Beijing. Asian importers with more than 80% of their Qatari contracted volumes currently under force majeure are living through exactly the supply concentration risk that an Alaska deal would partially hedge against. Without sufficient contracted volumes, no financing syndicate will greenlight a $55 billion project in a remote Alaskan location — and whether heads of agreement emerge before any FID announcement is the signal traders should track.1,4