DNR approves royalty cut for Kitchen Lights unit to extend Cook Inlet gas production

The Alaska Department of Natural Resources issued a final best-interest finding Feb. 5 approving a royalty modification for the Kitchen Lights unit operated by Fury Operating Alaska LLC (doing business as Hex Fury), the House Energy Committee heard Feb. 18. The modification reduces the state royalty on specified leases accessible from the Julius R platform from the standard 12.5 percent to 3 percent until the unit reaches a gross-revenue target of $712 million, DNR said.

DNR commercial analyst Weston Nash and Deputy Commissioner John Crother told the committee the change is designed to keep development drilling economically viable and to extend production life in a basin that has been in long-term decline. "The prior history of production was predominantly in these sixties, seventies, and eighties. And we are on a serious tail end of the production," Nash said.

Why it matters: DNR modeled several scenarios and concluded that without the modification the Kitchen Lights unit likely would have reached a cash-flow negative point by mid-2025 and could have ceased producing. Under the department’s central scenario, the royalty modification is expected to extend the unit’s productive life by about 10.5 years and yield about 63.2 billion cubic feet (BCF) of additional gas. DNR estimated the change would generate roughly $14.36 million in additional state royalty revenue and a total of about $36.4 million in incremental direct state revenue when combined with production and property-tax effects.

What DNR approved and why: The department said Fury provided the financial and engineering information required under state statute (AS 38.05.180(j)) to show the modification is in the state’s best interest and meets the "clear and convincing" standard cited in the finding. John Crother, deputy commissioner, told lawmakers DNR narrowed Fury’s original request to seven leases reachable from the unit’s existing Julius R platform and modeled capital and operating costs, expected well performance and prices before issuing the finding. "Fury provided sufficient information that confirmed the royalty modification was in the best interest of the state, and they provided the clear and convincing evidence as required," Crother said.

Committee discussion and modeling assumptions: Committee members pressed DNR on modeling choices. DNR officials said their production outlook assumes a flat, in‑state demand profile for the forecast period and focuses on supply-side scenarios to assess whether development drilling will be economical. Officials described a range of modeled price and production cases; variations in price largely drove state royalty outcomes in their runs. DNR told the committee it validated near-term drilling and development plans with operators during the annual review used to build the forecast.

Context about Cook Inlet production: Department slides shown to the committee stressed that most Cook Inlet fields are decades old; four fields (Beluga River, Kenai, Ninilchik and North Cook Inlet) accounted for about 72 percent of 2024 production, and their average start dates were more than 60 years ago. DNR staff said operators drilled 19 development wells in 2024 but only about 60 percent of those were producing when the department prepared its materials, underscoring drilling risk in mature reservoirs. The department’s development-drilling forecast through roughly 2030 assumed about 90 wells across fields in the known-development case.

Risks and operational issues: Committee members and DNR staff discussed several operational risks that can interrupt production from individual wells — for example, a safety valve test and subsequent outage that took KLU A2 off production until it was redrilled. DNR noted the Alaska Oil and Gas Conservation Commission (AOGCC) controls some well-testing authority and is the regulatory body responsible for safety testing; DNR said it would defer to AOGCC on any changes to testing practices. Committee members also asked about overriding royalty interests created before unitization; DNR explained those interests remain a property right for the life of the lease and transfer with lease assignments.

Conditions and oversight: DNR told the committee the royalty modification is tied to the unit operator’s plan-of-development commitments. The department said it will monitor implementation and that the determination was narrowed geographically to leases accessible from existing infrastructure. DNR also signaled continued, close engagement with other near-term projects — including the Cosmopolitan (Bluecrest) unit and Hillcorp’s field plans — and said it expects operators to meet POD commitments tied to approvals.

What the committee will do next: Committee members indicated they may pursue broader policy questions about Cook Inlet royalty policy and consumer impacts in future sessions, including whether different legislative direction is warranted as Cook Inlet moves toward primarily in‑state use of gas. DNR officials said the administration has not proposed legislative changes and that the department will continue to use its existing statutory authority to evaluate future royalty-modification requests.

The House Energy Committee adjourned after the presentation. The committee plans to turn to small and rural energy projects at its next meeting.