Alaska LNG is a proposed, two-phase natural-gas project—not just an export terminal. Its first phase is designed to treat North Slope gas and move it south by pipeline for use in Alaska. A second phase would add a liquefaction plant and marine terminal near Nikiski so the gas could be shipped overseas as liquefied natural gas (LNG). The complete system is not described in the cited records as operating.
How would Alaska LNG work?
The proposed system would connect North Slope gas production to Alaskan users and, if its export facilities were built, to overseas buyers. Gas would be gathered and treated on the North Slope, sent through a long-distance pipeline, and then either delivered for in-state use or liquefied for marine transport. The project sponsor describes those purposes as Phase One and Phase Two, respectively. Alaska LNG project overview
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- Gather North Slope gas. The proposed gas treatment plant would receive gas associated with North Slope production. The design includes connections to Prudhoe Bay and Point Thomson.
- Treat the gas for transmission. At the treatment plant, gas would be prepared to travel through the mainline pipeline.
- Move it south. The pipeline would run from the North Slope toward Cook Inlet and the Kenai Peninsula, generally following the Trans-Alaska Pipeline System and highways. Compressor stations would support movement along the route, with a heater station also included in FERC’s design description.
- Deliver it in Alaska or prepare it for export. Phase One is intended to supply Alaskans. Phase Two would add facilities near Nikiski to cool the gas into LNG and load it for shipment by sea.
This is a proposed chain of facilities and uses; the cited project descriptions do not establish an operating export chain or a completed supply contract.
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What is included in each phase?
| Phase | Proposed facilities and function | Intended destination |
|---|---|---|
| Phase One | North Slope gas treatment plant, connecting lines, and the long-distance pipeline system to move treated gas south. | Alaskan users. The project sponsor describes domestic supply as the first phase; this description is not evidence of a finalized supply contract. |
| Phase Two | Liquefaction plant and marine terminal near Nikiski, in addition to the upstream and pipeline system. | LNG for overseas shipment. The cited sources establish a proposed export design and an export application, not actual exports. |
The phases describe different intended uses and infrastructure additions, not competing versions of the project. Phase Two depends on more than the pipeline: it would require the liquefaction and marine facilities as well as the upstream gas and transportation system.
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Where would the pipeline go, and how large is the proposed system?
FERC’s March 6, 2020 final environmental impact statement (EIS) describes an approximately 806.9-mile, 42-inch mainline. Its route would generally follow the Trans-Alaska Pipeline System and highways south before continuing toward Cook Inlet and the Kenai Peninsula. Federal summaries sometimes round the mainline length to approximately 807 miles. FERC final EIS
| Design element | Published figure | What the figure means |
|---|---|---|
| Mainline pipeline | Approximately 806.9 miles; 42 inches in diameter | FERC’s 2020 proposed-design description, not a measurement of an operating line. |
| North Slope connections | One approximately 1-mile Prudhoe Bay connection and one approximately 62.5-mile Point Thomson connection | Connections included in FERC’s 2020 design description. |
| Compression and heating | Eight compressor stations and one heater station | Stations included in FERC’s 2020 proposed design. |
| Gas treatment | One gas treatment plant | FERC’s 2020 description of the proposed system. |
| Average inlet design capacity | Up to 3.7 billion standard cubic feet per day | FERC’s 2020 design figure; it is capacity, not actual daily throughput. |
| Peak inlet design capacity | Up to 3.9 billion standard cubic feet per day | FERC’s 2020 design figure; it is a peak design capacity, not a sustained operating rate. |
| LNG facility design | Up to 20 million metric tons per year | Alaska Gasline Development Corporation’s proposed facility design as described by FERC in 2020. |
The 20-million-metric-ton annual facility design figure should not be confused with the project’s later export application. In a February 23, 2026 notice, the U.S. Department of Energy (DOE) described an application by Alaska LNG Project LLC to export up to 20 million metric tons per year for a 30-year term. DOE’s stated conversion factor of 46.467 billion cubic feet per million metric tons equates that requested volume to about 929 billion cubic feet per year. These are requested and design quantities, not evidence of actual production, sales, or exports. DOE export docket notice
Would Alaska LNG supply Alaskans before exporting gas?
The sponsor’s phase plan puts in-state delivery first: Phase One would bring gas south for Alaskan users, while Phase Two would add export facilities. That is the project’s stated sequence and intended purpose. It does not by itself establish which customers would receive gas, the terms or volumes of supply, or when deliveries would start. The DOE materials described below also distinguish an export request from a completed long-term contract.
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Regulatory milestones need to be separated by agency and date. FERC recorded that it authorized the Alaska LNG Project on May 21, 2020. The federal permitting dashboard later recorded that DOE granted rehearing of a final order in 2021 and that the project was reopened to include DOE preparation of a supplemental environmental impact statement. Those steps do not support describing the entire project simply as “fully permitted.” FERC Alaska Gas Projects · Federal Permitting Dashboard
FERC states that it authorizes the siting and construction of onshore and near-shore LNG import or export facilities under Section 3 of the Natural Gas Act and conducts environmental reviews for proposed facilities within its jurisdiction. That role is distinct from DOE’s export authorization process. FERC’s explanation of LNG jurisdiction
As described in DOE’s April 2026 semiannual report, the project had no long-term LNG export or gas supply contracts at the time covered by that report, and an early-works implementation plan had been filed for Phase One. Those statements are tied to the report’s timeframe and do not establish the status after it. DOE April 2026 semiannual report
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The cited records do not establish a verified current total project cost or a final investment decision date. DOE’s February 2026 notice reproduces the applicant’s description of the project as unusually substantial in size, scope, costs, required upstream development, and schedule; that characterization is the applicant’s position in a DOE docket notice, not an independent DOE finding.
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What did FERC’s environmental review conclude?
FERC’s final EIS evaluated expected effects during construction and operation and identified avoidance, minimization, and mitigation measures. Its summary says most impacts would either not be significant or could be reduced to less-than-significant levels through proposed or recommended measures, while also identifying some adverse and significant impacts. That is a qualified finding in the EIS, not a conclusion that the project would have no significant impacts.
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What remains uncertain?
- Construction and operation: The cited design and authorization records do not mean the complete project has been built or is operating.
- Commercial arrangements: DOE’s April 2026 report described no long-term export or gas supply contracts at the time it covered.
- Cost and investment timing: The cited sources do not establish a verified current total cost or a final investment decision date.
- First exports: An export application and proposed capacity do not establish when exports would begin, or that they will occur.
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