Alaska for Sale
Contributed by Dana Raffaniello
The Carbon Dump, the Credit Harvest, and the $2 Billion Federal Subsidy Hidden Inside an LNG Bill
The governor’s own consultant told the Senate Finance Committee that gas is not the driver of the Alaska LNG pipeline. He declined to name the actual driver. Here it is.
On May 27, 2026, the first day of the Alaska Legislature’s special session, GaffneyCline consultant Nicholas Fulford told the Senate Finance Committee that gas is not the driver of the AKLNG project’s economics. He declined to name the actual driver. No legislator asked what it was.
The driver is more than $2 billion per year in federal tax credits. Approximately $595 million annually in 45Q carbon capture credits, flowing to the private operator at $85 per ton from Alaska’s geology. And $1.5 billion annually in 45V clean hydrogen credits, flowing from a Nikiski facility that turns North Slope gas into qualifying hydrogen at 500,000 metric tons per year. Both streams flow entirely outside Alaska’s tax reach. The Legislature has never seen a fiscal note that quantifies either one.
Alaska’s return under HB 50, the 2024 carbon storage law that makes the 45Q credits possible, is $2.50 per ton in injection royalties. The operator collects $85. Alaska collects $2.50. The ratio is 34 to 1 in the operator’s favor, from Alaska’s geology, under a regulatory framework Alaska built and paid for.
This is not a surprise. The governor described this architecture publicly for four years. In June 2022, he told reporters in Japan that Alaska could supply clean hydrogen for decades to come. In December 2022, he published an op-ed titled “Alaska’s Map to Clean Hydrogen Leadership,” describing the pipeline as the feedstock mechanism for a hydrogen production platform, while AGDC submitted an $850 million DOE hydrogen hub application for a Nikiski facility. In April 2024, the White House committed in writing to exploring cross-border carbon dioxide transport hubs between Alaska and Japan. The Alaska DNR presented that commitment as a featured legislative slide. The governor pitched clean hydrogen across Asia. He asked the Legislature to vote on a gas bill.
Under the proposed legislation, Alaska surrenders $7 billion in state tax revenue and $13 billion in municipal revenue through 2063. In return, Glenfarne has proposed charging Alaskan ratepayers approximately $16 per thousand cubic feet for gas. The Department of Revenue’s own estimate for imported LNG in 2033 is $17 per thousand cubic feet. A decade ago, the Municipal Advisory Group negotiated $628 million per year in municipal payments with ExxonMobil, BP, and ConocoPhillips. The current legislation produces $86 million per year for all government recipients combined. That comparison has not appeared in any committee document or floor statement.
There is also the matter of where the carbon goes. HB 50 enabled the import of foreign industrial carbon dioxide for permanent injection into Alaska’s geology. The Cook Inlet basin sits above the Aleutian subduction zone adjacent to the Castle Mountain Fault, which the USGS documents as the only fault in Southcentral Alaska with both historical seismicity and recent surface rupture. A magnitude 6.0 earthquake struck 30 to 40 miles from Anchorage on Thanksgiving Day 2025. The trust fund HB 50 created for long-term monitoring stops collecting after 12 years. The CO2 stays underground indefinitely. Monitoring liability transfers to Alaska taxpayers permanently with no cost cap. Alaska exports energy to Japan. Under this framework, Alaska then receives Japan’s industrial emissions back for underground storage at $2.50 a ton while the operator collects federal credits from the same ground.
Alaska holds real leverage here. The 45Q credit requires Alaska’s pore space. The 45V credit requires Alaska’s gas and Alaska’s pipeline. Without Alaska’s geology and the regulatory framework Alaska built, the operator collects neither. Article VIII, Section 2 of the Alaska Constitution requires development of Alaska’s resources for the maximum benefit of its people. A contractual share of the combined credit stream applied to reduce the in-state tariff would deliver gas to Alaskan utilities below $4 per thousand cubic feet while giving the state more than $400 million per year in recurring revenue tied to the project’s actual economic engine. That negotiation has not happened.
The special session runs through June 19. No vote has been taken. Contact your legislators at akleg.gov or call the legislative switchboard at 907-465-4648. Ask where the fiscal note is that quantifies the 45Q and 45V credit streams flowing to the operator from Alaska’s geology. If it does not exist, that answer belongs on the record before any vote is taken.
Dana Raffaniello lives in Palmer, Alaska. He works as a network engineer, reads Alaska energy legislation closely, and publishes analysis of its fiscal and structural implications at raff6482.substack.com. He is running for the Mat-Su Borough Assembly, District 2. He has no commercial interest in any energy project discussed in this analysis.