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E3 tells FSEC region faces possible near‑term reliability gap; portfolio approach and some gas capacity recommended
Summary
Consulting firm E3 reported a near‑term Pacific Northwest resource‑adequacy gap of about 9 gigawatts by 2030 (growing to 14–18 GW by 2035) and recommended a diversified portfolio of wind, solar, transmission, storage and some natural‑gas capacity to meet multi‑day winter events and long‑term clean‑energy goals.
Consulting firm E3 presented technical results to the Energy Facility Site Evaluation Council, telling members that the region likely faces a near‑term resource adequacy deficit and will need substantial new capacity and transmission to meet electrification and clean‑energy targets.
Arnie Olson, a senior partner at E3, told the council: "we did find a near term resource adequacy gap" and said the study quantified that gap at "about 9 gigawatts by 2030," growing to between "14 and 18 gigawatts by 2035." He explained this gap stems from a combination of rising load (from electrification of buildings and transportation) and retirement of firm generation.
Olson said the region's reliance on hydropower shapes the nature of reliability events — multi‑day cold snaps during low‑hydro years — and that batteries alone are insufficient to meet long duration energy needs: "batteries in particular for the whole region are very low, only about 6% of nameplate" in effective capacity. He said the modeling consistently favored a portfolio solution: "energy efficiency, wind, solar, geothermal, some battery storage, some new transmission, and some new natural gas generation," and that adding limited gas capacity was a robust finding across cases.
Mary Wienke, executive director of the Public Generating Pool, said the study grew out of a January 2024 event that strained the system and was supported by a broad set of publicly owned utilities. Wienke emphasized coordinated planning and the need to communicate study results to stakeholders.
E3 presented scenario results showing the scale of potential build‑out — tens of gigawatts of wind and solar and thousands of megawatts per year of new capacity — and estimated regional investment on the order of billions of dollars per year to meet higher electrification scenarios. Olson noted modeling uncertainty around hydro operations and load forecasts and fielded council questions about long‑duration storage and siting lessons from other regions.
Council members asked about emerging technologies (for example, longer‑duration iron‑air batteries) and siting and permitting practices used in other states; Olson and Wienke pointed to California and other regions for lessons on staffing, process efficiencies and fee structures to support permitting workloads.
The presentation concluded with an agreement to continue the conversation in other venues and with regulator working groups.
