On January 7, 2025, the Treasury Department and the Internal Revenue Service released final rules for the Clean Electricity Production Tax Credit under section 45Y and the Clean Electricity Investment Tax Credit under section 48E of the tax code. The rules, published in the Federal Register on January 15 as Treasury Decision 10024, implement the technology-neutral credits created by the Inflation Reduction Act. From the start of 2025, these credits replace the older technology-specific production and investment tax credits under sections 45 and 48 for projects placed in service after December 31, 2024. The existing credits remain available for projects that began construction before 2025.
The rules confirm which zero-emissions technologies qualify, including wind, solar, hydropower, marine and hydrokinetic energy, geothermal, nuclear and certain waste energy recovery property. Treasury said the final rules largely maintained the approach of the June 2024 proposal. The timing is notable. The rules were finalized two weeks before a change of administration, with the incoming Republican majority in Congress openly discussing cuts to Inflation Reduction Act credits to pay for extending the 2017 tax cuts. Our view is that the rules are well designed and provide the clarity developers need, but that investors should treat them as the current law of a contested regime, not a settled one. Projects that can start construction quickly have an advantage.
What the credits do
The technology-neutral credits are structured around emissions rather than fuel type. Any facility that generates electricity with a greenhouse gas emissions rate of zero or below qualifies, whether it uses a technology that exists today or one developed later. Developers may choose either the production credit, paid per kilowatt hour over ten years, or the investment credit, calculated as a percentage of eligible capital costs. Standalone energy storage also qualifies for the investment credit.
As under the Inflation Reduction Act's other credits, the full value requires meeting prevailing wage and registered apprenticeship standards. Bonus credits are available for projects that meet domestic content thresholds, that are located in so-called energy communities with a history of fossil fuel employment, or that serve low-income communities. Credits can be transferred to unrelated buyers for cash, and some tax-exempt and public entities can elect direct payment. Those features have opened the tax credit market to a much wider range of investors.
What the final rules settle
The rules clarify several issues that had held back some investment decisions. They set out how the zero-emissions list is maintained, and confirm that any future changes to the list, or to the lifecycle analysis models used to assess combustion and gasification technologies, must be supported by analysis from the Department of Energy's national laboratories. That reduces the risk of arbitrary changes.
They also provide rules for combustion and gasification technologies, such as biomass or renewable natural gas, to qualify in future if they can demonstrate net zero lifecycle emissions. Treasury said the national labs were already analyzing certain biomass technologies. For existing plants, including nuclear units, the rules address how incremental capacity added to a facility can qualify, which matters for uprates.
The rules also set out how projects that combine qualifying and non-qualifying equipment, or that are expanded over time, should be treated, including a rule on when integrated operations at a single site count as one facility. These details sound technical, but they determine whether a large hybrid solar and storage project or a phased wind farm receives the full credit.
Why technology neutrality matters
The shift from technology-specific credits to an emissions-based test is the most important long-term feature of the regime. Under the old system, Congress had to name each eligible technology and periodically extend credits that were due to expire, which created repeated cliffs and lobbying battles. The new structure qualifies any zero-emissions generator automatically and phases the credits down only when US power sector emissions fall to 25 percent of 2022 levels, or after 2032 if later. That gives developers of newer technologies, such as advanced geothermal, small modular reactors and long-duration storage, a credible incentive without needing a new act of Congress.
The political backdrop
The credits are now at the center of the federal budget debate. Republican leaders have signaled that rolling back parts of the Inflation Reduction Act is on the table, and the incoming administration has expressed hostility to wind energy in particular. Changes would require legislation, since the credits are written into the tax code, and budget reconciliation offers a path that needs only a simple majority in the Senate.
Several factors complicate a full repeal. A large share of the clean energy manufacturing and generation investment since 2022 has gone to Republican-held congressional districts, and some Republican members have urged leaders to preserve the credits. Utilities, including those in conservative states, have built the credits into their resource plans. Nuclear and geothermal enjoy bipartisan support. The most likely outcome, in our view, is a narrowing of the credits, with earlier phase-outs for wind and solar and tighter restrictions on Chinese supply chains, rather than outright repeal.
What developers should do
For projects in development, the priority is to establish that construction has begun under existing IRS guidance, either by starting significant physical work or by incurring at least 5 percent of total project costs. Projects that begin construction under current law have historically been protected from later changes, although that convention is not guaranteed. Developers should also review supply chains in light of likely foreign entity restrictions, since provisions aimed at China have broad bipartisan support.
For buyers of tax credits, transfer agreements should address the risk of changes in law, including indemnities and the allocation of risk if a credit is reduced or eliminated. For utilities and large electricity buyers, resource plans and power purchase agreements should include scenarios with lower or no credits for wind and solar after 2027 or so.
Our assessment
Treasury's final 45Y and 48E rules are a well-constructed framework that gives developers and investors the clarity they asked for. The technology-neutral design is sound policy and should outlast any single administration. But the credits face their most serious political test this year. Developers that move projects into construction quickly, clean up their supply chains and price policy risk into their contracts will be best placed, whatever Congress decides.