Alaska LNG Project (also called AKLNG) is a major natural gas infrastructure initiative—not an oil pipeline—to transport stranded natural gas from Alaska’s North Slope to in-state users first, with a second phase enabling LNG exports.
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It is developed by Glenfarne Alaska LNG, LLC (a subsidiary of Glenfarne Group, LLC), which owns 75% and serves as lead developer, in partnership with the State of Alaska (25% ownership via the Alaska Gasline Development Corporation/AGDC through 8 Star Alaska LLC). Glenfarne took over as lead developer in March 2025 after signing definitive agreements with AGDC, shifting more development risk and costs to the private sector while the state retains a long-term stake.
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The project is structured in two financially independent phases to accelerate execution and prioritize in-state energy needs:
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Phase One (Domestic Pipeline Focus): A 739-mile, 42-inch-diameter mainline pipeline (potentially including a 63-mile, 32-inch Point Thomson Lateral) to deliver natural gas from the North Slope (Prudhoe Bay Unit gas treatment plant area) to Southcentral Alaska (Cook Inlet/Anchorage region). It will supply reliable, affordable gas to homes, businesses, utilities (e.g., ENSTAR), industry (e.g., Donlin Gold mine), and power generation amid declining Cook Inlet supplies. Pipeline construction planned in four simultaneous spreads/sections.
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Phase Two (LNG Export Addition): Adds the LNG liquefaction terminal and related infrastructure at Nikiski on the Kenai Peninsula, extending the total pipeline length to ~807 miles and enabling up to 20 million tonnes per annum (MTPA) of LNG exports (primarily to Asia). Includes associated facilities like a gas treatment plant (GTP) on the North Slope.
alaska-lng.com
Pipeline capacity is designed for approximately 3.3–3.5 billion cubic feet per day (Bcf/d) of natural gas, supporting both in-state use and full export volumes.
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Current status and timeline (as of mid-May 2026): All major federal permits are in place (FERC certificate, DOE export authorization). Worley Limited completed primary front-end engineering and design (FEED) for Phase One by the end of 2025 and has been provisionally selected for Engineering, Procurement, and Construction Management (EPCM) services; final engineering and cost estimating are underway.
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Early pipeline-related construction/prep work (e.g., site preparation, mobilization) was targeted to begin as early as mid-April 2026 per a February 2026 FERC filing, with full mobilization around June 2026. Main pipeline construction (pipe-laying) is expected to ramp up in late 2026 across multiple seasons, aligning with Arctic conditions.
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Mechanical completion of the Phase One pipeline is targeted for 2028, with first in-state gas delivery in 2029.
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Phase Two (LNG terminal) Final Investment Decision (FID) is eyed for late 2026/early 2027, with first LNG exports potentially in ~2031.
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FID on Phase One (pipeline) is still pending (originally targeted for late 2025 but delayed slightly into 2026), but momentum is strong with recent commercial milestones. Glenfarne aims for it once financing thresholds are met (typically ~80% of offtake contracted).
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Commercial progress:Gas supply: Executed or advanced 30-year precedent agreements with major North Slope producers including ExxonMobil, Hilcorp Alaska, ConocoPhillips (recent 30-year deal announced around May 18–19, 2026), Great Bear Pantheon, and others—now sufficient volume for Phase One FID.
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LNG offtake (exports): Preliminary long-term agreements/LOIs covering ~13 MTPA (out of 16 MTPA targeted for financing the full 20 MTPA project) with buyers including TotalEnergies (2 MTPA LOI, Feb 2026), JERA, Tokyo Gas, CPC (Taiwan), PTT (Thailand), and POSCO. These support Asian market diversification.
glenfarnegroup.com
Other partners: Conditional construction awards to major contractors (e.g., MasTec/Precision, Quanta/Price Gregory, Michels, VINCI, etc.); line pipe supply deals (e.g., Corinth Pipeworks, Europipe, POSCO steel); Baker Hughes (compressors/power); Danaos (LNG carriers and $50M investment).
glenfarnegroup.com
Cost estimates: Older public figures around $44 billion for the full project; Alaska Dept. of Revenue updated to ~$46 billion recently, though sponsors have not released the latest definitive number and critics note it could be higher. Some tax relief or state support may be needed.
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Benefits emphasized by developers: Thousands of jobs during construction/operations, state/local revenues, reduced energy costs and pollution for Alaskans, and geopolitical energy security via reliable LNG to allies.
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The project has strong bipartisan Alaska political support and aligns with federal priorities for domestic energy and exports, though it faces ongoing scrutiny on final costs, binding contracts, and subsidies. For the absolute latest, check the official site (
alaska-lng.com) or Glenfarne’s newsroom. This remains a gas (not oil) project and is unrelated to any second 48-inch crude oil line parallel to TAPS.
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Explain Alaska LNG project economics
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Is the AKLNG 42 inch pipeline running adjacent to the 48 inch TAPS line, meaning within 100 meters parallel, or is the path quite different ?
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No, the AKLNG (Alaska LNG) 42-inch natural gas pipeline does not run adjacent to the TAPS 48-inch oil pipeline within 100 meters parallel along its full route—the paths are only partially aligned in the northern section and quite different overall.
alaska-lng.com
Here’s the breakdown based on official project descriptions, regulatory filings, and route analyses:Northern section (Prudhoe Bay to ~milepost 400 south of Livengood): The AKLNG mainline generally parallels TAPS and follows the existing Dalton Highway/Trans-Alaska Pipeline utility corridor for roughly the first half of its length (up to about Livengood in Interior Alaska). This maximizes use of established infrastructure.
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However, it is not continuously adjacent within 100 meters (~328 feet). Approximately 36% of the entire AKLNG route (~290 miles total) is “collocated” within 500 feet (~152 meters) of existing rights-of-way, including TAPS specifically for about 89 miles (mostly in the North Slope Borough and Yukon-Koyukuk Census Area).
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In those collocated segments, the new pipeline runs parallel at varying distances (up to the 500-foot threshold), with engineered separations for safety, constructability, and regulatory compliance. It crosses TAPS itself 12 times (plus 5 crossings of the TAPS fuel gas line).
phmsa.dot.gov
Southern section (south of Livengood onward): The routes diverge sharply. AKLNG turns south to roughly parallel the Parks Highway (through areas like Nenana, Denali, and Matanuska-Susitna Boroughs), then heads southwest, crosses Cook Inlet underwater, and terminates at the LNG facility in Nikiski on the Kenai Peninsula.
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TAPS, by contrast, continues southeast from the Fairbanks area via the Richardson Highway corridor to its marine terminal in Valdez (Prince William Sound). The southern halves of the two pipelines are hundreds of miles apart and follow entirely separate alignments.
In summary: The AKLNG route is deliberately designed to share the northern TAPS/Dalton corridor where practical (for environmental, permitting, and cost reasons), with limited close-parallel sections within the broader utility corridor. But it is not a tight “adjacent/parallel within 100 meters” duplicate of TAPS for any extended distance, and the overall paths become quite different after central Alaska. This is confirmed across FERC environmental impact statements, PHMSA filings, and project materials from Glenfarne Alaska LNG and the Alaska Gasline Development Corporation.
phmsa.dot.gov
For the most visual confirmation, the official interactive Alaska LNG project map (available on
alaska-lng.com) overlays the route against TAPS and highways—clearly showing the partial northern overlap followed by divergence. The project remains focused on gas delivery to Southcentral Alaska (with later LNG export capability), independent of the oil-focused TAPS.