GVEA ran short on generation reserves 236 of last 250 days

Golden Valley Electric Association ran short on generation reserves 236 of the last 250 days, more than 94% of the time, staff told the co-op's board at a special work session Aug. 13. Staff called it a reliability-risk measure, not a sign the utility can't serve members right now.

Staff blamed significant generation issues, fuel shortages and grid stability problems. They recommended a second LM6000 turbine at the North Pole Power Plant, which already holds the necessary air and water permits. The unit could burn naphtha now, switch to natural gas if it becomes available, and let aging North Pole diesel units shift back to reserve duty instead of primary generation. The board took no action. CEO Travis Million said there is no zero-risk option.

The co-op has had no Anchorage-area natural gas-generated power since February 2025. Bradley Lake Hydro construction outages are expected to cut low-cost hydropower each first quarter through 2034, when Interior demand peaks. Six industrial accounts supplied 44% of GVEA's kilowatt-hours sold in 2025. Losing the two largest Interior gold mines over reliability concerns could raise the residential utility charge as much as 28%. Installed capacity, above 300 megawatts, isn't the same as power available when it's needed, staff said.

GVEA flagged the squeeze in February 2025, blaming Bradley Lake transmission construction on the Kenai Peninsula and the Cook Inlet gas shortage. Members are already paying: the cost-of-power surcharge rose from $0.12779 to $0.20652 per kilowatt-hour on June 1, about $47 a month more for a household using 600 kilowatt-hours.

An outside consultant's study last year tested more than 100,000 scenarios against a Lower 48 benchmark of one shortfall per 10 years. GVEA's current generation mix modeled roughly 17 shortfall events a year. A second LM6000 paired with battery storage under the co-op's PACE program came in at 0.0 to 0.1 shortfall events. Wind and storage help, staff said, but only dispatchable generation closes the gap.

The $80 million scenario showed a $10.3 million increase in the utility charge against a $39.5 million drop in fuel and purchased power costs, including about $35 million a year in fuel savings. Staff projected a 4.95% cut in the effective rate, or $10.63 a month for an average residential member.

Members who spoke were split. Some cited fossil fuel reliance and a past used-turbine purchase as concerns; one backed the second unit for reliability. The regional Railbelt Integrated Resource Plan, presented by Railbelt Reliability Council CEO Ed Jenkin, isn't expected to win Regulatory Commission of Alaska approval before the second quarter of 2027, after GVEA is set to decide. Staff will ask the board for direction Aug. 25. Any project would still need RCA preapproval as a Large Energy Facility.