The bill adds a new Section 48F to the Internal Revenue Code to create a 30% investment tax credit (ITC) for the basis of eligible ‘hydropower improvement property’ placed in service. Eligible work includes fish passage technologies, water-quality and sediment‑transport improvements, dam safety upgrades, public-access improvements, removal of obsolete nonpowered obstructions, and certain small ‘approved remote dams’ and associated interconnection equipment.
The provision also makes the credit eligible for elective payment (direct pay) and for transfer under existing Code provisions, applies progress-expenditure rules for long projects, and is effective for property placed in service after December 31, 2022. By tying energy investment incentives to ecological and safety outcomes, the bill aims to steer capital toward projects that both produce clean power and address river- and dam-related environmental and safety concerns.
At a Glance
What It Does
Establishes a 30% ITC for the basis of qualifying hydropower improvement property placed in service; applies construction progress rules from section 46; and requires written approval from FERC or appropriate state/local officials for eligible projects before January 1, 2032.
Who It Affects
Owners and operators of FERC‑licensed hydropower dams and nonpowered dams targeted for removal, rural utilities running small remote hydropower plants (≤20 MW), engineering and construction contractors, and lenders or tax credit investors who finance such upgrades.
Why It Matters
The credit couples clean‑power incentives with explicit river‑restoration and dam‑safety categories, and the inclusion of elective payment and transferability makes the credit financeable by tax‑exempt or low‑tax owners—potentially accelerating many projects that previously struggled to attract tax equity.
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What This Bill Actually Does
The bill creates a new investment tax credit modeled in form on existing energy ITCs: taxpayers may claim a credit equal to 30% of the basis of ‘hydropower improvement property’ placed in service in a taxable year. The statute lists eligible categories of work—improving fish passage (new or upgraded turbines and fishways), actions that maintain or improve water quality, measures that promote downstream sediment transport and habitat maintenance, upgrades to meet federal dam safety and security standards, public‑use and access improvements consistent with FERC licenses or settlement agreements, removal of obsolete river obstructions, and placing into service ‘approved remote dams’ and their interconnection property.
Projects must receive written approval from the Federal Energy Regulatory Commission or appropriate state or local officials before January 1, 2032 to be eligible. The text borrows progress‑expenditure rules from section 46 to accommodate multi‑year construction and specifies that certain interconnection equipment may qualify.
The bill defines ‘‘approved remote dam’’ narrowly (licensed before December 31, 2020; exclusively serving communities not interconnected to the three main interconnections; maximum net output ≤20 MW; and ‘‘does not contribute to atmosphere pollution’’), which targets small, isolated generating sites.To improve access to the credit for entities that don’t have large tax liabilities, the bill adds the new credit to the list of credits eligible for elective payment under section 6417 and extends transferability rules under section 6418, including a mechanism that allows many taxpayers to elect treatment as an applicable entity for purposes of direct pay for this credit. The bill also makes conforming changes to related Internal Revenue Code provisions so the new credit integrates with existing basis, recapture, and energy tax accounting rules.Finally, the bill’s effective date is retroactive to property placed in service after December 31, 2022.
That retroactivity and the January 1, 2032 approval deadline are likely to shape project timing, permitting strategies, and financing structures because both regulators and applicants will need to document approvals and eligible expenditures to claim the ITC.
The Five Things You Need to Know
The credit equals 30% of the basis of qualifying hydropower improvement property placed in service for the taxable year (a new section 48F).
Eligible activities explicitly include fish passage technologies, water‑quality and sediment‑transport improvements, dam safety upgrades, public‑access improvements, removal of obsolete nonpowered obstructions, and certain small remote dams and their interconnection equipment.
Taxpayers must obtain written approval from FERC or appropriate state or local officials for any eligible property prior to January 1, 2032 in order to claim the credit.
The bill adds the credit to the list eligible for elective payment (direct pay) under section 6417 and into the transfer rules of section 6418, expanding finance options for tax‑exempt owners and low‑tax entities.
The changes are effective for property placed in service after December 31, 2022, and apply progress‑expenditure rules from section 46 to accommodate long‑duration projects.
Section-by-Section Breakdown
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Creates the 30% investment tax credit
This subsection establishes the core ITC: a credit equal to 30% of the basis of hydropower improvement property placed in service during the taxable year, and it plugs the credit into the existing section 46 framework. Practically, that means owners claim an investment‑style credit against income tax liabilities tied to qualifying capital expenditures rather than a production or PTC‑style credit tied to generation.
Applies progress‑expenditure rules
The bill makes rules similar to section 46(c)(4) and (d) applicable, which addresses how to treat long‑running construction projects and progress expenditures for the credit. For projects that span multiple tax years, this provision preserves the ability to claim credit based on costs paid or incurred during construction under specified safe harbors, reducing the risk that long lead‑time dam projects will lose eligibility.
Defines eligible hydropower improvement property and special categories
This portion lists eligible property types and provides key definitions. It enumerates environment‑ and safety‑oriented categories (fish passage, water quality, sediment transport, dam safety, public access, removals) and creates the ‘‘approved remote dam’’ carve‑out with four specific criteria (licensed before 12/31/2020; serves non‑interconnected communities; ≤20 MW; doesn’t contribute to atmospheric pollution). It also defines ‘‘interconnection property’’ in line with the technical requirements of section 48(a)(8)(B), which matters for what transmission‑related equipment can be included in basis.
Adds the credit to direct‑pay and transfer regimes
The bill inserts the new credit into the elective payment (section 6417) list and makes it transferable under section 6418. It also creates an election path that lets certain taxpayers who would otherwise not qualify as ‘‘applicable entities’’ be treated as such for the direct‑pay option—but only with respect to this credit—expanding access to non‑taxpaying owners including many public and nonprofit entities.
Adjusts related energy tax code sections
Conforming edits add the new credit into the cross‑references in sections 46, 49, and 50 so the ITC interacts properly with energy credit aggregation, basis computation, and recapture rules. These changes ensure the new credit is recognized in depreciation and recapture calculations and harmonized with existing energy investment rules.
Retroactivity and approval deadline
The statute applies to property placed in service after December 31, 2022, and separately requires written approval for eligible projects prior to January 1, 2032. The combination of retroactivity and a long but finite approval window creates administrability and documentation considerations for both taxpayers and regulators.
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Explore Energy in Codify Search →Who Benefits and Who Bears the Cost
Every bill creates winners and losers. Here's who stands to gain and who bears the cost.
Who Benefits
- Owners/operators of FERC‑licensed hydropower facilities — They can claim a 30% ITC for retrofit, safety, and ecological upgrades, lowering net capital costs on projects that extend plant life or improve environmental performance.
- Rural utilities and operators of small remote dams (≤20 MW) — The ‘approved remote dam’ carve‑out and inclusion of interconnection property make upgrades to isolated systems more financeable, particularly where tax appetite is limited.
- Conservation and river‑restoration project sponsors — Removals of obsolete nonpowered obstructions and investments in fish passage are explicitly eligible, creating a new funding route for ecological work tied to hydropower projects.
- Engineering, construction, and equipment manufacturers — Increased project activity for fishways, turbine retrofits, dam rehabilitations, and interconnection work will generate new procurement and contracting opportunities.
- Tax‑exempt entities and low‑tax owners (public utilities, municipal authorities, tribes) — Elective payment (direct pay) and transferability options improve access to value for entities that cannot fully use traditional tax credits.
Who Bears the Cost
- Federal Treasury — The direct‑pay and transferability provisions enlarge budgetary exposure by turning a nonrefundable credit into a federal outlay for some claimants.
- FERC and state/local licensing and permitting agencies — Agencies will face increased administrative workload and documentation requests because written approvals are necessary for eligibility and will likely be contested in borderline cases.
- Project developers and owners who miss the approval window — Entities that cannot secure required written approvals by January 1, 2032 lose eligibility, so hurried or poorly documented projects risk denial and potential recapture disputes.
- Tax compliance and finance teams — Owners and financiers must develop new compliance systems to document approvals, segregate eligible basis, apply progress‑expenditure accounting, and coordinate with lenders or transferees.
- Environmental stakeholders and communities — While some will benefit, others may bear indirect costs if the credit incentivizes upgrades that prioritize generation or access over full river restoration, requiring monitoring and advocacy resources.
Key Issues
The Core Tension
The bill attempts to reconcile two legitimate goals—expanding low‑carbon, resilient electricity from existing dams and restoring river ecosystems—but in doing so it simultaneously subsidizes both dam retention/upgrades and dam removals; that creates a design tension where the fiscal incentive may not align neatly with ecological objectives and where timing, approval, and definitional gaps could determine whether projects prioritize power output, safety, or true river restoration.
The bill ties energy tax incentives to environmental and safety outcomes but leaves key procedural and definitional questions unresolved. It requires ‘‘written approval’’ from FERC or ‘‘State or local officials, as appropriate’’ but does not specify which state or local entities qualify, what form the written approval must take, or how approvals for multi‑jurisdictional projects are coordinated.
That ambiguity creates risk for developers who must time permitting and financing to the January 1, 2032 approval cutoff. The retroactive effective date to projects placed in service after December 31, 2022 further raises documentation and audit exposure for projects already completed or underway.
Substantive tradeoffs also deserve scrutiny. The statute’s eligible list includes both removal of obsolete nonpowered obstructions and reconstruction/upgrades of existing dams.
Those provisions can push policy in two opposite directions—removing a barrier to restore river function, or preserving and modernizing dams to produce power and improve safety. Because both activities are credit‑eligible, project selection may tilt toward whichever path better captures refundable or transferable credit value rather than solely on ecological merit.
Finally, the ‘‘approved remote dam’’ definition contains operational criteria (exclusively servicing non‑interconnected communities, licensed before 2021, ≤20 MW, and ‘‘does not contribute to atmosphere pollution’’) that will necessitate interpretive guidance—especially the atmospheric pollution clause, which is unusual for hydropower rules and could generate disputes over backup generation or lifecycle emissions.
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