Transferable tax credits (TTCs) are a transformative mechanism to accelerate investments into US energy and manufacturing and help corporations manage corporate tax liability. TTCs provide notable advantages, streamlining tax credit monetization for sellers while reducing tax liability for buyers.
In this guide, we’ll review the essential information that transferable tax credit buyers, sellers, and intermediaries need to know to leverage this opportunity fully, including:
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The Inflation Reduction Act, passed in 2022, permits certain federal clean energy and manufacturing tax credits to be sold for cash, creating a more efficient way to deploy and recycle capital. Buyers earn a discount on the credits, reducing their tax liability and making participation in clean energy finance more appealing. These private transactions take the place of grants or government refunds, which require the Internal Revenue Service (IRS) to directly arbitrate the provenance of a credit.
The ability to freely sell tax credits in a robust private market has several distinct advantages:
The impacts of transferability are already on display — TTCs have catalyzed more than $500 billion in private capital since 2022.
The 11 federal tax incentives for clean energy are:
Historically, zero-emissions energy project developers were required to enter joint ventures and leasing arrangements with other private companies with sufficient tax liability to capture the full value of the major clean energy tax credits, such as the investment tax credit (ITC) and production tax credit (PTC). These arrangements are known as "tax equity" and are relatively complex financing structures. In a tax equity relationship, tax investors invest directly into partnerships with developers and receive a special allocation of cash, tax credits, and depreciation in exchange.
Traditional tax equity deals are structurally complex and generally require domain knowledge as well as monitoring and oversight capabilities. Consequently, they are often limited to large projects with experienced sponsors and significant credit volumes. Smaller or newer developers often can’t meet these thresholds.
The transfer market offers a simpler, more scalable alternative that allows a wider range of participants to monetize credits and unlock capital. Transferability is still a private market mechanism. It relies on the private sector to conduct appropriate due diligence, preventing fraud and ensuring that buyers and sellers in tax credit transfer deals retain “skin in the game.”
Transferability also creates opportunities for a wider range of technologies. While tax equity has historically been limited to established clean energy technologies such as wind and solar, TTCs have a broader scope, including nuclear, hydrogen, geothermal, biogas, and advanced manufacturing.
This flexibility not only drives economic growth in terms of domestic manufacturing, but also incentivizes innovation in the development and commercialization of next-generation clean energy technology.
That investment comes at an opportune time — energy demand is rising for the first time in decades, driven by artificial intelligence (AI), cloud computing, and domestic manufacturing. Transferability provides powerful incentives to invest in and build the energy infrastructure that will be required to deliver reliable, affordable electricity.
The tax credit transferability feature for various clean energy tax credits included in federal legislation allows a larger universe of corporate taxpayers to take advantage of the credits because they do not require complicated tax equity structures. Tax credit transferability is a simpler structure and should entice a much bigger pool of corporate taxpayers to participate in clean energy project financing.
With more buyers, a larger pool of developers and manufacturers should benefit from the ability to monetize their tax credits and the simpler process for doing so. Tax credit monetization plays a significant role in capitalizing clean energy projects, so more capital access should be a catalyst for many developers and manufacturers, especially those that may not have established relationships with tax equity providers.
Read more: Benchmarking corporate participation in the tax credit market
At Crux, we're creating the capital platform that will enable sellers and buyers to transact tax credits with clarity and confidence:
Our expert team, market-validated standards, and purpose-built tools streamline transaction execution for all parties, facilitating more investment in clean energy and critical infrastructure.
Sellers and buyers complete a transfer election statement, including the registration number, which is attached to the sellers and buyers’ tax returns. Importantly, according to Treasury guidance, “not all steps need to occur in the order displayed,” and “a transferee taxpayer may take into account a credit that it has purchased, or intends to purchase, when calculating its estimated tax payments.” This process principally affects filing and does not prevent deals from being signed and funded.
Advisors play an important role in providing diligence, insurance, and indemnification for buyers of TTCs:
A credit buyer’s critical review will focus on:
Stakeholders will look at appraisals, cost-segregation reports, and legal/tax opinions.
Buyers will also want to ensure that the typical series of project documents is in place (e.g., engineering, procurement, and construction agreement, interconnection agreement) and evaluate the credit support and creditworthiness of the developer.
Crux’s purpose-built tools streamline the diligence process. The Crux data room will automatically populate market-validated diligence checklists, making it easy for buyer counsel to identify documents and request additional materials directly in the platform.
Indemnities are a key protection for buyers in TTC transactions, offering contractual remedies if the credits are later disallowed or recaptured. Rather than participating in project cash flows, buyers rely on these protections to mitigate risks tied to credit ineligibility or project noncompliance.
Coverage amounts are typically negotiated, with many buyers seeking indemnities equal to at least 100% of the credit value to cover potential penalties or interest. Deal terms may include “make-whole” provisions (ensuring full reimbursement), as well as caps, survival periods, and liability limitations.
Insurance is a key type of indemnity that helps protect buyers by offering additional security in case a seller cannot fulfill their obligations. In transferable tax credit transactions, tax insurance policies are commonly used to cover risks such as credit disallowance or recapture, especially when a developer has limited creditworthiness or when buyers want added assurance beyond other negotiated indemnities.
Crux has observed insurance coverage levels below 100% in situations where insurance is a credit-enhancement tool for a seller. However, insurance coverage ranging from 90–140% is substantially the most common coverage percentage. A small portion of deals include coverage in excess of 140%, up to 165%. The seller typically covers the cost of insurance coverage, which ranges from 2–5% of the insured limit of the credit, depending on coverage and sizing.
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Any eligible taxpayer (under the IRS definition) can take advantage of tax credit transferability, meaning that tax-exempt organizations are generally ineligible. Corporations and even individuals can buy tax credits.
While the buyer can be an individual, they will be subject to active and passive activity restrictions — the face value of transferable tax credits can only be used to offset tax liabilities from passive, non-investment income.
Some high-net-worth individuals and family offices that have previously participated in the tax equity market may find TTC deals appealing if they can time the payout closer to their tax-filing date. However, we do not expect the tax credit market to open widely to individuals.
Timing varies depending on several factors, including internal approval timelines, due diligence complexity, and other factors. On average, tax credit transfer deals facilitated by Crux close in about three months.
Below is a sample timeline:
Total timeline: 3.5-–8.5 months (with an indicative internal time investment of 20–40 hours)
Preparation phase (1–4 months):
Transaction phase (5–11 weeks):
Credits are typically sold at a discount to their face value, indicated as cents on the dollar (e.g., a $0.93 TTC price indicates a 7% discount to the face value of the tax credit).
Investment-grade versus non-investment-grade ITC and PTC pricing, 2025
Internal rates of return on tax credit transactions are particularly high, and corporations are doing their best to time credit purchases with their quarterly estimated payments. Most taxpayers set aside cash to make tax payments, including quarterly estimated payments.
Those funds would not normally generate a return; companies cannot choose between paying taxes and building factories. With tax credit transferability, reserved cash suddenly has the capacity to generate a real cash return, making TTCs a uniquely attractive investment.
Transaction costs can include fees for advisors, legal counsel, syndicators, and due diligence efforts such as appraisals or cost-segregation reports. These costs vary depending on deal complexity and size. The seller typically covers these fees up to a negotiated cap, though exact terms may vary by transaction.
With transferability, the risk of the IRS not respecting the tax equity partnership as valid is eliminated because no partnership exists. However, there may still be a need to demonstrate the true third-party nature of the transaction. Project cash flow risk is much less of a concern so long as the project remains operational and solvent, given that the tax credit buyers do not participate in the project cash flows.
Still, there are some key risks that buyers and sellers will have to navigate, particularly in the case of ITCs:
In the context of transferable tax credits, recapture is the risk that tax credits may be reclaimed if the project fails to meet certain requirements. Generally, developers will have to continue indemnifying buyers for this risk as they have historically done, and insurance will play a key role. Even with insurance, project viability will remain important to buyers. Credit buyers won’t participate in project cash flows but will still need to be confident the project will remain in service through the five-year recapture period. Recapture risk only applies to projects that generate investment tax credits.
As with tax equity, the developer will be responsible for maintaining and operating the system throughout the recapture period and supporting whatever indemnities it gives to the buyer. A developer declaring bankruptcy and abandoning a project could trigger recapture. A benefit of transferability is that, after the recapture period, the transaction with the tax credit buyer is fully resolved.
One of the more important risks is ensuring that the stated basis level is eligible for tax credits. Some credit sellers may be historically accustomed to “stepping up” the value of a development project through a sale to a tax equity partnership before monetizing the credit, allowing the ITC to be calculated based on fair market value rather than project cost. However, in a direct transfer, credits are generally valued based on cost rather than market value, making accurate cost basis documentation critical.
The valuation of these items requires careful monitoring and evaluation. Developers typically provide the engineering, procurement, and construction (EPC) agreement, along with an appraisal and cost-segregation report, as part of diligence.
Many of these risks (especially those related to basis or recapture) are covered by insurance. The seller of the credit commonly covers these insurance costs, though buyers may choose to purchase uninsured credits at a steeper discount.
Federal tax policy entitles the tax credit buyer to carry the TTC forward for 22 years and back for 3 years, meaning that the buyer has up to 22 years of future tax filings to utilize the full value of the credit. They can also carry the tax credit back and apply it to previous years, as far as three years in the past.
However, the carryback is not as simple as applying the credit to the previous year’s return:
Companies will have filed tax returns during these periods, so applying tax credits to previous years requires refiling taxes for as many as three previous tax years, and thus may be a prohibitively complex process.
Carryback process for transferable tax credits
In the rapidly developing TTC market, one of the biggest challenges is the timing gap (like in the tax equity market). Developers and manufacturers want to move forward with as much certainty and commitment as possible, while buyers want to outlay cash as close to quarterly estimated payments as possible.
With that in mind, final guidance from the IRS has confirmed that transferable tax credits can be applied to tax liabilities in the same year they are generated. This means buyers should complete the purchase before the end of the tax year so they can claim the credits.
It’s also important to remember that the seller and buyer must complete the IRS pre-filing process, which can take several weeks. Timing deals and negotiations correctly is critical.
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In general, buyers seek to align purchases of TTCs with their quarterly estimated tax payments. This can create a seasonal rhythm to deal activity, though the exact timing of transactions varies based on market dynamics and available supply.
Buyers also assume certain risks when purchasing tax credits and, as such, are likely to pay more for credits that are perceived as being lower risk. While buyer priorities differ, they consistently place a premium on counterparties that can offer strong indemnities — whether through a parent guarantee, robust balance sheet, or tax insurance — which helps provide greater certainty around credit support and risk allocation.
While the market for tax credit transferability is still fairly new, it’s maturing quickly. We see transferable tax credit pricing organized into tranches with pricing estimates reflecting relative risks (as discussed above).
According to the IRS, eligible entities that wish to pursue a transferable tax credit transaction may take the following steps (noting that not all steps need to occur in the order listed below):
Federal tax policy provides valuable bonus tax credits (also known as “adders”) for projects that meet certain criteria.
Tax credits with applicable bonus adders
The prevailing wage and apprenticeship (PWA) bonus tax credit allows projects to claim a 30% investment tax credit — a 5x multiple on the 6% base rate — if they meet specific wage and apprenticeship requirements during construction and for five years post-service.
Projects that began construction before January 29, 2023, are grandfathered into the 30% ITC and are not required to meet PWA standards. Today, PWA-compliant projects are generally considered the baseline assumption for credit valuation.
Another valuable tax credit bonus is available to projects that meet domestic content adder requirements. To claim this adder, companies must demonstrate that projects meet domestic content standards for steel or iron constituent parts and manufactured goods.
If a project meets these standards, it can claim an additional 10-percentage-point bonus tax credit, boosting its ITC value to 40% of its base cost from 30% (for projects that meet PWA requirements).
Projects developed in communities or census tracts designated as energy communities can claim an additional 10-percentage-point increase in credit value. The IRA defines energy communities as:
Projects developed in low-income communities or communities designated as historic energy communities may access additional bonuses. The low-income communities bonus tax credit program is available to solar and wind projects under 5MWac that are installed in low-income communities or on tribal land.
Projects meeting these benchmarks can access a 10-percentage-point bonus above their baseline ITC or PTC rate. Alternatively, a 20-percentage-point credit increase is available to eligible solar and wind facilities that are part of a qualified low-income residential building or a qualified low-income economic benefit project.
Sellers typically cover transaction fees up to a negotiated cap. In addition to these fixed costs, the gross purchase price for TTCs would include costs associated with insurance and transaction fees. Insurance premiums, which are paid by the seller, often cost 2–5% of the insured limit of the credit (depending on deal size and risk), and deal fees range from 0.5–3.0%. Sellers are also typically responsible for the cost of their own legal counsel, as well as any appraisal or cost-segregation reports required to support credit eligibility.
For instance, if a project sponsor sells a credit for $0.90 gross (a 10% discount to the face value of the credit), obtains insurance for 2.75% of the face value of the credit, and pays a fee to an intermediary or broker for 1.25% the credit value, they will realize net proceeds of $0.86. If the buyer of the credit incurs $50,000 in additional advisory fees related to conducting due diligence on the transaction, and the seller has agreed to cover these fees up to that amount, then these costs would also be subtracted from the TTC sale to estimate the seller’s proceeds.
While transferable tax credits have broadened access to clean energy financing, tax equity can still be a strong option for developers seeking to monetize all available tax benefits. A key advantage is the ability to monetize accelerated depreciation, such as modified accelerated cost recovery system (MACRS) deductions, which can be especially valuable for capital-intensive projects. These benefits cannot be transferred and are only available to investors who are legal partners in the project, as in traditional tax equity structures.
Tax equity may also allow for a step-up in basis, increasing a project’s valuation from cost to fair market value and boosting the size of the ITC. This step-up generally requires a partnership structure and isn’t available in direct credit transfers, which are based on cost. For large projects or experienced sponsors, traditional or hybrid structures may offer more value. These “T-flip” models combine tax equity and transferability to balance simplicity with maximum benefit.
Transferable tax credit transaction timelines vary based on deal complexity, documentation readiness, and market conditions, but are typically faster and more flexible than traditional tax equity deals. On average, deals facilitated by Crux close in about three months. In contrast, tax equity deals often take six to twelve months due to bespoke structuring and deal complexity.
Ultimately, tax credit buyers prefer to transact with counterparties who are “ready to go,” which means organized, PWA-compliant sellers can often move faster from interest to close. To make this easier for sellers, Crux’s purpose-built diligence tools streamline documentation, automate workflows, and help accelerate clean energy transactions with greater efficiency.
For investment tax credits, the tax credit is generated when the facility is complete and placed in service. Importantly, projects that intend to claim the ITC but have regular, multi-year construction timelines may claim partial credits for qualified production expenditures (QPEs). These QPE credits are not eligible to be sold or transferred; only the ITC generated in the year the project is placed in service can be transferred.
Production tax credits are generated after a project enters service and begins producing energy. PTCs are generated for each unit of production (e.g., a megawatt-hour of electricity or a kilogram of hydrogen) for a long period of time — 10 years under the new federal tax policy.
Developers and manufacturers can sell forward a stream of future PTCs (or a “strip”), either as a production tax credit deal or as a tax equity transaction. Typically, a developer or manufacturer will sell a conservative estimate of their future PTCs in a forward transaction to minimize the risk that the facility will not generate enough energy in a year to meet the required supply of PTCs. Excess PTCs generated in each year can also be sold as “spot” PTCs, which must be sold in the tax year in which they are generated (or before the extended tax filing date for that year).
Buyers of tax credits often choose to execute transactions as close as possible to the end of their tax year (when they have the greatest certainty around their tax liabilities).
Bridge financing has become an increasingly important tool for clean energy developers and manufacturers seeking to access capital ahead of tax credit monetization. These short-term loans allow project sponsors to borrow against expected tax credit proceeds, helping to cover construction costs and improve cash flow while waiting for credits to be generated and sold.
Crux has observed growing lender appetite in this space as the market for transferable tax credits has matured. Today, multiple lenders are actively underwriting tax credit bridge loans for both ITCs and PTCs. These loans typically require a forward commitment from a buyer, providing the repayment certainty lenders need before the credit is delivered.
It’s worth noting that bridge loan pricing and terms depend on several factors, including developer creditworthiness, documentation quality, and the presence of enhancements such as insurance. To support these transactions, Crux offers a debt capital markets solution, connecting developers with a network of active lenders while providing tools and data to streamline execution.
Whether you’re a developer or manufacturer, tax credit buyer, or tax advisor, Crux can help you make the most of the transferable tax credit market. With expert guidance, market-validated documentation, and a purpose-built platform, we’ll help you streamline your transactions and reduce risk.
