Public power utilities have four practical funding routes in 2026: elective pay for clean energy tax credits, DOE grid resilience programs under the Bipartisan Infrastructure Law, USDA Rural Utilities Service electric loans, and state-administered formula funding. The pandemic-era stimulus programs that dominated funding guidance are closed to new commitments, and elective pay now carries a hard placed-in-service deadline that makes timing the binding constraint.
Most funding guidance written for public power utilities is out of date, and the way it is out of date matters. It points at money that is no longer available. For a municipal electric utility running lean, that wasted planning time is expensive, and it is time not spent on the operational data that electric utility management software exists to keep current.
The Coronavirus State and Local Fiscal Recovery Funds, which anchored a generation of utility funding advice, had an obligation deadline of December 31, 2024, with funds required to be expended by December 31, 2026. If your utility did not obligate those funds by the end of 2024, that route is closed. Guidance still recommending CARES Act or American Rescue Plan money as a live opportunity is describing a window that shut.
The same applies to two programs that appear repeatedly in older articles. The Smart Grid Investment Grant program and the Broadband Technology Opportunities Program were both created under the 2009 American Recovery and Reinvestment Act, not the Bipartisan Infrastructure Law, and both concluded years ago. Building a capital plan around either is a waste of a planning cycle.
What replaced them is different in structure. The current landscape is less about one-time stimulus rounds and more about ongoing tax credit monetisation and formula funding that flows through your state. That changes who you talk to and when. Utilities evaluating platform investments alongside funding decisions will find the same logic in our municipal utility software buying guide.
Is your current capital plan built around a program that still accepts applications?
It is worth checking before the next budget cycle, because the answer is frequently no.
Two structural points shape how a small public power utility should approach this.
Elective pay is the largest change, and it is not a grant. It is a mechanism that lets tax-exempt entities monetise credits they previously could not use. Applicable entities include states and political subdivisions such as local governments, rural electric cooperatives, and agencies and instrumentalities of state and local governments, which covers municipal electric utilities directly.
USDA RUS is more accessible than most municipals assume. The electric program makes insured loans and loan guarantees to nonprofit and cooperative associations, public bodies, and other utilities, and the guaranteed loan program has been expanded to finance generation, transmission, and distribution. Applications are accepted on an ongoing basis from October 1 through September 30, so there is no single window to miss.
Elective pay deserves separate treatment because it changed what public power can do, and because it is now on a clock.
Before it existed, a municipal utility building solar or storage could not use the federal tax credits that made those projects viable for investor-owned utilities, because a tax-exempt entity has no tax liability to offset. Elective pay converts the credit into a direct payment. That is a genuine structural shift rather than an incremental program.
Three things about its current state matter for planning.
The phase-out accelerated. H.R. 1, the One Big Beautiful Bill Act of 2025, signed in July 2025, accelerated the phaseout of these credits. Most wind and solar projects now need to be placed in service before 2028 to receive a credit. Placed in service is not the same as started, contracted, or funded. For a utility whose capital projects run multi-year timelines, that deadline is closer than it reads.
New foreign entity rules apply from 2026. Foreign entity of concern rules take effect for taxable years beginning after enactment, which for public power utilities on a calendar year is January 1, 2026. Compliance requires demonstrating that no more than 15 percent of the entity's debt is owned by certain foreign entities. This is a documentation exercise most utilities have never had to run against their own debt structure.
Payments are protected from sequestration for now. H.R. 5371, the Continuing Appropriations and Extensions Act, 2026, waives statutory PAYGO at the end of the year, which protects Build America Bond, New Clean Renewable Energy Bond, and elective pay payments from elimination through sequestration.
If a generation or storage project has to be placed in service before 2028, when does construction have to start?
Working backward from that date is the single most useful planning exercise available to a public power utility this year. The wider context is covered in our review of electric utility industry trends for 2026.
The old guidance got one thing right, and it remains the most useful distinction in this area.
For a utility with a small team, formula funding is usually the better first target. Under Section 40101(d), states, territories, and tribes receive non-competitive allocations and request the funds annually, then distribute to utilities in their jurisdiction. That means your competition is other utilities in your state, and your relationship with the state energy office matters more than grant-writing capacity.
Competitive programs are worth pursuing when you have a specific, engineered, shovel-ready project. The DOE Grid Deployment Office administers a $10.5 billion GRIP program aimed at grid flexibility and resilience against extreme weather, which is real money but attracts sophisticated applicants.
Yes, through elective pay under section 6417 of the Inflation Reduction Act. Applicable entities include states and political subdivisions such as local governments, rural electric cooperatives, and agencies and instrumentalities of state and local governments. The credit is paid directly rather than offsetting tax liability, which is what makes it usable by a tax-exempt utility.
No, not for new commitments. State and Local Fiscal Recovery Funds had to be obligated by December 31, 2024 and expended by December 31, 2026. Funding guidance that still presents CARES Act or American Rescue Plan money as an opportunity is describing a closed window.
Following H.R. 1 in July 2025, the phaseout accelerated, and most wind and solar projects need to be placed in service before 2028 to receive a credit. Placed in service is a stricter test than started or contracted, so multi-year project timelines should be planned backward from that date.
No. Under Section 40101(d), states, territories, and tribes receive non-competitive allocations and request them annually, then distribute within their jurisdiction. Your application relationship is with your state energy office, not with DOE.
Yes. The Electric Infrastructure Loan and Loan Guarantee Program makes insured loans and loan guarantees to nonprofit and cooperative associations, public bodies, and other utilities serving eligible rural areas, and applications are accepted on an ongoing basis from October 1 through September 30.
SMART360 keeps asset records, condition data, work history, and billing on one platform, so the documentation a funding application requires already exists rather than being assembled against a deadline.
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