Alaska LNG is a proposed system to bring natural gas from the North Slope to Alaskans and, in a later phase, turn some of that gas into liquefied natural gas (LNG) for export. Its planned route includes a gas treatment plant, a roughly 807-mile pipeline to the Kenai Peninsula, and a proposed liquefaction and marine terminal near Nikiski. The complete system is not described in the cited records as operating.
How would Alaska LNG work?
The project is designed as a connected chain: gather North Slope gas, treat it, move it south by pipeline, then either deliver it for use in Alaska or—if the export phase is built—liquefy it for shipment by sea. The project sponsor describes in-state gas delivery as Phase One and export infrastructure as Phase Two. That is the proposed sequence, not evidence that Phase One supply or Phase Two exports are already underway.
- Gather gas on the North Slope. The proposed system would receive gas associated with North Slope production, with connecting pipelines described for Prudhoe Bay and Point Thomson.
- Treat the gas. A gas treatment plant would prepare the gas for transport through the mainline pipeline.
- Move it south. The mainline would carry gas toward Cook Inlet and the Kenai Peninsula, with compressor stations helping move it along the route.
- Use it in Alaska or prepare it for export. Phase One is intended to supply Alaskans. Phase Two would add a liquefaction plant and marine terminal near Nikiski, where gas would be cooled into LNG for shipment.
The sponsor’s project overview describes the two-phase concept; the Federal Energy Regulatory Commission (FERC) final environmental impact statement describes the facilities and route reviewed for the project.
Where would the pipeline go, and what facilities are proposed?
FERC’s 2020 environmental review describes an approximately 806.9-mile, 42-inch-diameter mainline pipeline running from the North Slope toward the Kenai Peninsula. The route would generally follow the Trans-Alaska Pipeline System and highways south before continuing toward Cook Inlet. The project design also includes a gas treatment plant, short connecting lines from Prudhoe Bay and Point Thomson, eight compressor stations, and one heater station.
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The export facilities would be near Nikiski, on the Kenai Peninsula. The pipeline route and associated facilities are part of the project proposal reviewed by FERC; they should not be confused with an existing operating gas-export network.
How do Phase One and Phase Two differ?
| Phase | Proposed facilities | Intended purpose | What the cited records establish |
|---|---|---|---|
| Phase One | North Slope gas treatment and the pipeline system to the Kenai Peninsula, including connections and compressor facilities | Deliver gas to Alaskans | The sponsor describes this as the first phase. DOE’s April 2026 report notes an early-works implementation plan filing for Phase One; that filing is not proof that the phase is complete or operating. |
| Phase Two | A liquefaction plant and marine terminal near Nikiski, in addition to the upstream and pipeline system | Cool gas into LNG and ship it to global markets | The export facilities are part of the proposed project. DOE’s February 2026 notice describes an application request for export authorization, not actual LNG shipments. |
Phase Two depends on more than having a pipeline in place: an export chain would require the proposed liquefaction and marine facilities as well as gas supply and commercial arrangements. The cited sources describe the project design and regulatory record, not a completed export contract or operating supply chain.
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What are the proposed capacity and export figures?
These are design or application figures, not measured throughput. FERC’s 2020 review describes the proposed facility and pipeline design; DOE’s February 2026 notice describes a later export-authorization request.
| Figure | Meaning and qualification |
|---|---|
| Up to 3.7 billion standard cubic feet per day average inlet capacity; 3.9 billion standard cubic feet per day peak | FERC’s 2020 description of the proposed gas treatment plant’s inlet design capacity. |
| Up to 20 million metric tons of LNG per year | FERC’s 2020 description of the proposed facility design—not actual production. |
| 20 million metric tons per year; about 929 billion cubic feet per year | The export quantity Alaska LNG Project LLC requested in its application, as described by DOE in February 2026. The approximate gas equivalent uses DOE’s conversion factor of 46.467 billion cubic feet per million metric tons. The request is not evidence of approved or realized exports. |
What is the project’s regulatory status?
FERC authorized the Alaska LNG Project on May 21, 2020, according to the agency’s Alaska Gas Projects page. That authorization is one dated milestone in a longer federal review history; it is not, by itself, a basis to call the full project built, operating, or fully permitted in every respect.
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The federal Permitting Dashboard records that the Department of Energy (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. The dashboard’s status information extends through February 2026.
FERC says it authorizes the siting and construction of onshore and near-shore LNG export and import facilities under Section 3 of the Natural Gas Act and prepares environmental reviews for proposed facilities within its jurisdiction. DOE has a separate role in export authorizations. FERC’s description of its jurisdiction is available on its LNG page.
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What is known about export plans and commercial readiness?
In a notice dated February 23, 2026, DOE described Alaska LNG Project LLC’s request to export up to 20 million metric tons annually for a 30-year term. That is an application request, not confirmation that exports will occur. The notice also characterizes the proposed project’s size, scope, costs, required upstream development, and timeline as unusually substantial compared with LNG projects in the lower 48. The characterization appears in the DOE docket notice and should be understood in that context, rather than as a completed project cost or schedule.
DOE’s April 2026 semiannual report says the project had no long-term LNG export or gas supply contracts at the time covered by that report and notes the Phase One early-works implementation plan filing. Those are dated statements, not confirmation of the project’s status after April 2026. The cited records do not establish a verified current total cost or final investment decision date, so neither can be stated as settled here.
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What did FERC’s environmental review conclude?
FERC’s final environmental impact statement, issued March 6, 2020, reviews expected construction and operational impacts and identifies proposed or recommended avoidance, minimization, and mitigation measures. Its summary says most impacts would not be significant or could be reduced to less-than-significant levels with those measures, while also identifying some adverse and significant impacts. That is the finding in the 2020 environmental review; it does not mean the project has no significant environmental impacts.
Read the full FERC final EIS for the impact categories and mitigation details.
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