Transferable Tax Credits: A $42B Market Settling on Paper

Energy developers sold $42 billion of federal tax credits to corporate buyers in 2025, up 48% from $32 billion the year before, according to Crux's annual market report. Roughly a quarter of the Fortune 1000 now buys them. Investment-grade sellers cleared at 93 to 95 cents per dollar of credit. That is a market the size of the US high-yield new-issue calendar in a slow year, and nearly every dollar of it settled by wire against a negotiated transfer agreement, an IRS registration number and an insurance binder. It is worth asking what a digital capital market could do for it, and being honest about what it cannot.

How a credit actually changes hands

Section 6418 of the Internal Revenue Code, added in 2022, lets a project owner sell certain energy credits to an unrelated taxpayer for cash. The cash is not income to the seller and not deductible to the buyer. The seller must register the project with the IRS and obtain a registration number before the transfer, and both parties attach a transfer election statement to their returns, per the IRS guidance on elective pay and transferability.

The buyer takes on the risk that the credit is later disallowed or recaptured. For investment tax credits, recapture exposure runs five years from the placed-in-service date. Because the buyer cannot verify prevailing-wage compliance, domestic-content bonuses or placed-in-service dates from its own desk, the market has grown a diligence and insurance layer around every trade. Buyers hire counsel, sellers assemble data rooms, insurers underwrite the credit's validity, and the transaction closes weeks or months after the term sheet.

Pricing reflects all of that. Crux's data shows investment-grade sellers of investment tax credits at $0.940 per dollar in the first half of 2025 and $0.931 in the second, production tax credits at $0.950 and $0.940, nuclear credits at $0.962 and clean-fuel credits at $0.908. The gap between those figures and par is a combination of the buyer's return, the seller's credit quality, the recapture risk and the cost of getting the deal done. The most liquid segment was deals between $25 million and $100 million. Below that, pricing softens, because a fixed diligence cost is spread over a smaller credit.

Why the credit itself will not be tokenized

The obvious idea, splitting a credit into fractions and letting them trade, runs into the statute. Section 6418 permits one transfer. The buyer of a credit cannot resell it. That single rule removes the secondary market that a token would otherwise create, and no amount of engineering changes it.

There is a second constraint. A tax credit is useful only to a taxpayer with a federal liability to offset. A wallet address is not a taxpayer. A credit can only settle into the hands of a specific legal entity that will file a return, and that entity's identity, not its key, is what the IRS cares about. The credit is a tax attribute, not a security or a commodity, and it does not behave like either.

The One Big Beautiful Bill Act, signed in July 2025, preserved transferability for the life of the underlying credits but added restrictions on transfers to specified foreign entities and foreign-influenced entities, according to Kirkland & Ellis's analysis. That adds a counterparty screen to every transfer that is incompatible with anonymous transferability. So the answer to "can transferable tax credits be tokenized" is no, in the sense most people mean. Anyone telling a sponsor otherwise is selling something that will not survive contact with a tax adviser.

What around the credit can be

The credit is one cash event in a project's life. Everything around it is ordinary project finance, and ordinary project finance is exactly where digital capital markets have something to offer.

Start with the project company itself. A solar, storage or nuclear-adjacent project generates contracted revenue for twenty years or more. The credit sale is a lump sum that arrives once, usually in the first year, and de-levers the capital stack. The equity in the project company, or a portfolio of them, is a cash-flow asset with a verifiable revenue record, and it can be structured and issued the way other energy and infrastructure interests are, as set out in the energy and digital infrastructure pillar. The tax credit improves the underwriting of that equity. It does not need to be the thing that trades.

Next, the bridge. Developers commonly borrow against a signed credit transfer agreement to fund construction before the credit is generated and sold. That bridge loan is secured by a contract with a known counterparty, a registered project and, in most cases, an insurance policy. It is a short-duration credit with unusually well-documented collateral, and it fits the private credit structures that already exist for tokenized loans. The sponsor's incentive is speed: every week between the transfer agreement and the cash is carry cost.

Third, the data. The reason the transfer market discounts credits from smaller sellers is not that their projects are worse. It is that verifying a $15 million credit costs about the same as verifying a $75 million one. Placed-in-service documentation, wage and apprenticeship records, domestic-content certifications and the foreign-entity screens introduced in 2025 are all attestable facts. If they were published as structured, third-party-verified data when the project registers, rather than assembled into a fresh data room for each buyer, a portion of the discount that small sellers pay would disappear. Crux itself expects utility-scale solar pricing to improve by up to 1.5 cents between the third quarters of 2025 and 2026, and commercial-scale deals to recover up to 2 cents, as the market matures. Better verification is part of how that happens.

The 2026 construction deadline changes the supply curve

Sponsors should read the calendar. Under the July 2025 law, wind and solar projects that begin construction after July 4, 2026 must be placed in service by the end of 2027 to claim the credit at all. Projects that began construction before that date keep the older four-year continuity window. The predictable result is a wave of 2026 and 2027 vintage wind and solar credits, followed by a taper, while storage, nuclear, advanced manufacturing and clean-fuel credits continue on their own schedules.

Two things follow. First, the transfer market will be crowded in 2027, and buyers will have their pick of sellers. Sponsors with clean, verifiable documentation will clear at the top of the range; those without will pay for the diligence twice, once in time and once in price. Second, the assets that outlast the credit phase-out, storage and the projects already placed in service, become the durable base of the energy cash-flow market. Crux projects storage capacity roughly doubling to 88.6 gigawatts and clean energy capital investment rising about 7.5% to $125 billion in 2026 in its base case. That capital has to come from somewhere, and a growing share of it will be raised from investors who want a smaller ticket and a verifiable record rather than a fund commitment.

What a sponsor should do now

The practical sequence is straightforward. Register the project and assemble the credit documentation once, in a form a third party can attest to, rather than rebuilding it for each buyer. Sell the credit through the transfer market, because that is where it can legally go. Then treat the project equity and any bridge facility as the assets that can be structured for a broader investor base, with the credit sale as a documented event in their history rather than the product itself.

Commertize's view, as a digital capital markets platform working across energy, digital infrastructure, gold, carbon and commercial real estate, is that the transferable credit market is a useful case study. It shows that a $42 billion market can exist on bilateral paper, and it shows the price of doing so. The platform overview explains how verified cash-flow data, lower minimums and faster settlement apply to the project interests that sit around the credit, and the marketplace shows how energy interests are presented to holders once they are issued.

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