US Clean Energy Tax Credits: The Map After OBBBA

One Statute, Two Rewrites

The Inflation Reduction Act of 2022 built the current architecture: technology-neutral electricity credits (sections 45Y and 48E), a production credit per tonne of captured carbon (45Q), per kilogram of clean hydrogen (45V), per unit of clean energy components manufactured (45X), and per gallon of clean transportation fuel (45Z) — all of them monetisable through elective pay or by selling the credit for cash.

The One Big Beautiful Bill Act of July 4, 2025 (OBBBA) is the second rewrite. It terminated wind and solar electricity credits early, shortened the hydrogen window, extended the clean fuels window, restored full-value carbon capture parity for enhanced oil recovery, and attached prohibited-foreign-entity restrictions — the FEOC regime — to almost every credit on the list. Anyone still working from a 2024-era summary is planning against a statute that no longer exists.

The Six Credits at a Glance

Two cross-cutting sections carry the money: 6417 lets tax-exempt and public owners — and for 45Q, 45V and 45X even taxable owners, for five years — take the credit as a cash refund; 6418 lets everyone else sell it, once, for cash, to an unrelated buyer.

The Deadline Architecture

OBBBA created a strict hierarchy of dates, and every planning conversation now starts by placing the project on it:

• July 4, 2026 — wind and solar facilities that began construction by this date keep their four-year completion window; anything later must be in service by December 31, 2027 or gets nothing.
• January 1, 2026 — projects beginning construction from this date must clear the FEOC material-assistance ratios; earlier vintages escape the content test entirely.
• January 1, 2028 — last day to begin construction of a 45V hydrogen facility.
• December 31, 2029 — last sale year for 45Z clean fuel credits and for 45X metallurgical coal.
• December 31, 2032/2033 — 45X component phase-out completes; 48E/45Y non-wind/solar full value runs through construction starts in 2033, then 75% (2034), 50% (2035), zero after.

The beginning-of-construction rules themselves became litigation: Notice 2025-42 stripped the five percent safe harbor from wind and large solar in August 2025, and a federal court vacated that notice in full in June 2026, restoring the safe harbor — with the government’s next move still open as this article went to press.

FEOC: The Binding Constraint

The prohibited-foreign-entity regime is where most 2026-vintage projects will live or die. It works on three levels. First, a claimant test: specified foreign entities and foreign-influenced entities cannot claim credits at all. Second, a material assistance test for 48E/45Y facilities and 45X components: a cost ratio that must exceed a threshold that rises every year — for energy storage, 55% non-Chinese content in 2026, reaching 75% by 2030; for solar components sold in 2026, 50%, reaching 85%. Third, a ten-year payment rule: payments conferring effective control to a specified foreign entity after a 48E facility is placed in service claw back the entire credit.

It is a cliff, not a slope — a ratio one point short means zero credit — and the enforcement architecture is built to match: a one percent understatement threshold for penalties, a six-year assessment window, and supplier certifications signed under penalties of perjury. Treasury’s first computational guidance, Notice 2026-15, arrived in February 2026 with safe harbors keyed to the domestic content tables; statutory safe harbor tables are due by the end of 2026.

Turning Credits Into Cash

Most project owners cannot absorb tens of millions of dollars of credits against their own tax. The market answer is section 6418: a one-time, cash-only sale of the credit to an unrelated corporate buyer, registered with the IRS before filing. The buyer inherits recapture risk and a 20 percent penalty exposure on excessive transfers, which is why transfer prices track the quality of the seller’s substantiation — the evidence pack is the product.

Public and tax-exempt owners go the other way: section 6417 elective pay turns the credit into a refund cheque. One catch arrived on schedule in 2026: elective-pay projects over 1 MW that begin construction from 2026 must now meet domestic content requirements or lose the payment entirely, subject to narrow cost and availability exceptions.

Stacking With Clean Fuel Programmes

The federal credits are only half the revenue picture. Clean fuel standard programmes — California’s LCFS, Oregon and Washington’s programs, the BC LCFS and Canada’s CFR — pay operating credits on every unit of low-carbon fuel or charge delivered, on their own attribute accounting, on top of the federal capital or production credit.

• RNG and biofuels — 45Z federally, plus LCFS or CFR credits per unit, plus RFS RINs.
• Hydrogen — 45V per kilogram, plus LCFS and CFR Compliance Category 2 pathway credits on the same molecules.
• Storage and EV charging — 48E on the capital, then LCFS or CFR CC3 credits on every megawatt-hour dispensed to vehicles.
• Carbon capture — 45Q per tonne, while the CI reduction lifts the value of every fuel pathway downstream of it.

The combined stack, not any single programme, is what finances projects — and the carbon intensity file that sets the federal tier is the same file the fuel regulators verify. Building it once, to the stricter standard, is the whole trick.