This bill creates a new Washington electric transmission authority and a nine-member board (a new chapter in Title 43 RCW and new sections added to multiple RCW chapters). The authority is given powers to plan and support expansion of transmission capacity, develop community microgrids and distributed energy resources, pursue nonwires alternatives, coordinate upgrades and regional planning, own or partner on transmission projects under specified conditions, enter contracts and accept grants and federal assistance, and adopt rules to implement the chapter. The board appoints an executive director, sets staffing and compensation, meets at least quarterly, and must report activities to the governor and legislative committees (first report due December 1, 2025, then annually each September 1). The department of commerce must complete the first 20-year transmission needs assessment and a transmission system enhancement roadmap by October 30, 2026; the authority must update the assessment by October 30, 2031 and every five years thereafter. The authority may exercise eminent domain only to acquire rights-of-way for new transmission corridors, may own transmission equipment only as necessary to promote the public interest and must publish a divestment plan before ownership, may select qualified transmission builders or operators or, as a last resort, proceed to construction itself under rules, and may sell projects under a transparent rule-based process. The bill adds SEPA categorical exemptions for certain upgrades or rebuilding of existing lines and for grid-enhancing technologies, with required advance notification and tribal consultation through the Department of Archaeology and Historic Preservation and confidentiality protections for tribal information. It authorizes a limited utility rate incentive under chapter 80.28 RCW allowing up to a two percent increment to return on common equity for capital investments in grid-enhancing technologies and reconductoring with advanced conductors for projects installed after July 1, 2025; the commission may allow incentives through December 31, 2040 and must report to the legislature by December 31, 2029. The bill creates electric transmission operating and capital accounts in the state treasury, specifies sources and appropriation requirements for those accounts, and directs confidentiality and limited use of provider data for assessments. Separately, the bill establishes a treasury income account for earnings on invested surplus balances, directs monthly distributions and allocation of earnings to a long list of named state accounts and beneficiary permanent fund accounts based on average daily balances, assigns OFM responsibility under the federal Cash Management Improvement Act (CMIA) for necessary transfers and refunds, and states timing and constitutional allocation rules. Important parts of the act are incomplete or not shown in the provided text: some definitions referenced in section 2, the detailed rule criteria (including the definition of "qualified transmission builder or operator"), full executive director term mechanics, certain funding and bonding authority details (a bonding request must be prepared by November 1, 2025), and other amendments cited to RCW 43.84.092 and additional sections are not fully included here.

If enacted, the state would have a new public authority that can push transmission projects forward more actively than before: it can plan, partner, temporarily own or sell projects, use limited eminent domain for rights-of-way, and act as the lead for environmental and tribal consultations. That is likely to speed some upgrades and create new financing and fee flows — the state will hold separate operating and capital accounts that need legislative appropriation, counties/cities/towns/tribes could receive local investment fees tied to projects, and the Department of Commerce will produce a 20‑year needs assessment and roadmap that will guide where work happens. Utilities may be more likely to invest in reconductoring and grid‑enhancing technologies because regulators can grant up to a 2 percent return incentive for those investments through 2040, which could boost utility capital spending and potentially affect rates if regulators allow the incentive to be recovered from customers. The practical effects on stakeholders: transmission developers and utilities gain a new partner and a potentially faster permitting path for certain in‑right‑of‑way upgrades (due to SEPA exemptions and the authority’s ability to serve as SEPA and tribal consultation lead), tribes and local governments gain formal roles and potential fee revenue but also new project activity on lands they care about, and the state budget faces new appropriation decisions and a possible request for bonding authority by November 1, 2025. Key implementation details remain unclear from the provided text — for example how the authority will define a “qualified transmission builder,” the full scope of bonding authority and funding sources, and some governance specifics — so the timing and scale of these changes are uncertain.