Analyzing the Returns of Tax Credit Transfer Transactions
Published:
September 27, 2023
Updated:
December 10, 2024
10 min read
Analyzing the Returns of Tax Credit Transfer Transactions
When evaluating the economic benefits of a transferable tax credit purchase, buyers should consider how transaction timing can positively impact IRR and ROI.
Over the past year, we have talked to scores of potential buyers about the benefits and risks of acquiring transferable tax credits. Many measure their economic benefit in terms of the discount of the credit – i.e., how much they are willing to pay for a $1 reduction in their federal tax liability.
While important, the discount represents a single dimension to evaluate economic return. Payment terms for credits, as well as the potential impact on estimated taxes, are also key considerations.
In this article, we explore several hypothetical scenarios to understand how transaction timing impacts other key metrics, including internal rate of return (IRR) and return on investment (ROI).
Transaction scenarios under different payment terms
Let’s consider a transaction in which a corporate taxpayer, ABC Corp., is acquiring $100 of tax credits for a notional price of $90, reflecting a 10% discount. ABC is a C-Corporation, with estimated tax payments due on the fifteenth of April, June, September, and December. Its tax filing deadline is April 15 of the following year, but ABC makes an election to extend the date of its filing (and, for this example, we assume it files on September 15).
For purposes of this simplified analysis, we will assume that ABC does not calculate estimated taxes on an installment method but instead calculates estimated taxes based on equal quarterly payments.
Scenario 1: Sign and close at end of year, no estimated payment reduction
ABC identifies a tax credit opportunity in Q4 of their fiscal year and enters into a tax credit transfer agreement (TCTA) on December 31, 2024. ABC closes on the credit purchase simultaneous with the execution of the agreement and pays $90 on the same date.
Given the date of the purchase, ABC is unable to benefit from the reduction of estimated taxes throughout the year. Assuming it files its final tax return in September 2025, ABC receives a $100 benefit at that time through a reduction of its annual federal tax liability.1 The internal rate of return on this purchase would be 16%, and the ROI 11%.
Scenario 1: IRR of 16%, ROI of 11%
Scenario 2: Sign and close at beginning of year, four quarters estimated payment reduction
ABC identifies a tax credit opportunity early in the year and enters into a TCTA on January 31, 2024. As in scenario 1, it closes and pays for the credits simultaneous with the execution of the TCTA. (This would typically occur if a credit were generated early in the tax year; for instance, if a solar project was placed in service in January 2024.)
Scenario 2: IRR of 23%, ROI of 11%
ABC is able to reduce its four quarterly estimated payments by $25, reflecting an overall anticipated reduction of its federal tax liability of $100. The IRR impact of this transaction is 23%, while the ROI remains 11%.
Scenario 3: Sign and close mid-year, three quarters estimated payment reduction
Let’s assume that ABC identifies a tax credit opportunity and executes a TCTA on June 15, 2024. As in the previous scenarios, it closes and makes payment on the same date. In this scenario, ABC would have a cash outflow of $90 but realize an economic benefit of $50, as it would reduce its Q2 estimated tax payment by half of the tax credit purchased (reflecting the $25 of savings for each of Q1 and Q2). The net effect of its purchase on June 15 would be a $40 outflow.
In the next two quarterly payment dates, ABC would reduce its estimated tax payments by $25 each, producing an IRR of 82% and an ROI of 11%. (We realize that as the duration of an investment shortens, IRR becomes less meaningful as a metric.)
Scenario 3: IRR of 82%, ROI of 11% (As duration shortens, IRR becomes less meaningful.)
Scenario 4: Sign early year, close end of year, four quarters estimated payment reduction
In the transferability guidance released in June 2023, the IRS stated that a “transferee taxpayer [i.e., a tax credit purchaser] may also take into account a specified credit portion that it has purchased, or intends to purchase, when calculating its estimated tax payments…” (emphasis added). This is a favorable provision, as we’ll demonstrate in scenarios 4a and 4b.
Let’s assume that ABC identifies a tax credit opportunity early in 2024. It is a solar project that is expected to be placed in service in December 2024. ABC enters into a TCTA with the project owner in January 2024, but closing of the purchase and sale is conditional on the completion of the project. Therefore, the TCTA represents a binding, forward commitment to purchase credits from the project, but no payment is made until later in the year.
Given that the IRS guidance allows for ABC to reduce its estimated tax payments for credits it intends to purchase, and an executed TCTA is clear evidence for such intention, ABC would be able to reduce its four quarterly estimated tax payments by $25 and pay for the tax credits in December 2024 when the project is completed.
Once again, the ROI of the transaction remains at 11% (see Scenario 4a).2
Scenario 4a: ROI of 11%
In addition to reducing the buyer’s federal tax liability, this transaction has the benefit of generating working capital. Assuming the quarterly tax savings earn a conservative annualized return of 5%, the ROI of the transaction increases to 13% (see Scenario 4b).2
Scenario 4b: ROI of 13%
Keep potential scheduling delays in mind for ITC transfers
Keep in mind, project delays are a key risk for a buyer to evaluate in ITC transfer transactions when a project is anticipated to be completed late in the year. For example, if ABC reduced its quarterly tax payments throughout 2024, but the project in question was delayed into 2025, ABC would either need to find replacement 2024 credits from a different project or be subject to underpayment penalties.
IRR and ROI metrics represent post-tax returns for the buyer
In another favorable provision, the IRS affirmed that the buyer does not have gross income with respect to the discount of a purchased credit. Therefore, the IRR and ROI metrics discussed in this paper represent post-tax returns (the exception being the interest on working capital in Scenario 4b, which would be taxable).
To the extent that a corporate taxpayer is viewing tax credit purchases as an alternative to traditional treasury investments, it should keep in mind the post-tax nature of the return metrics.
Download our transferability economic model
To learn more, corporate taxpayers can download our transferability economic model and align it with their company's fact pattern.
Download Model
How Reunion can help
Reunion operates a managed tax credit marketplace and provides close transactional support with a keen eye to risk identification and management. With over 40 years of combined tax credit transaction experience, Reunion’s leadership team guides buyers, sellers, and their advisors through every phase of the transferability process.
Footnotes
1For this analysis, we will assume that ABC receives the benefit of the credit upon filing of its tax return. In reality, this may depend on other factors, including if and when ABC receives a cash refund for overpayments.
2IRR is not a meaningful metric in this scenario as inflows of cash precede any outflows.
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September 25, 2024
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Reunion Facilitates Over $1.6 Billion in Clean Energy Tax Credit Transfers in 2024
San Francisco, Sept. 24, 2024 /PRNewswire/ — Reunion, a leading clean energy finance company, today announced that it has facilitated the purchase and sale of over $1.6 billion in clean energy tax credits through Q3 2024.
Drawing on decades of clean energy financing experience, Reunion has transacted across a range of transferable tax credits – §48 ITCs, §45 PTCs, §45X AMPCs, and §30C alternative fuel infrastructure credits – and technologies. "Our team has facilitated dozens of tax credit transfers involving established clean energy technologies, like solar, wind, and battery storage, as well as emerging technologies, like biogas, fuel cells, and EV charging," said Reunion's president, Billy Lee."Advanced manufacturing and critical minerals, however, have been the largest areas of growth for us. We've executed §45X transactions from $10M to well over $500M."
Reunion recently published a study that estimates the size of the transferable tax credit market, and quantified the total credit market by monetization strategy (transfer, direct pay, retention and transfer). We estimate that over $45B in clean energy tax credits will be generated in 2024. Of this total, Reunion estimates that approximately $21B to $24B will be transferred – a significant increase from the $5B to $7B in transfers Reunion estimated in 2023.
"At the end of 2023, many buyers were hesitant to be 'first to market.' A year later, however, the vast majority of corporate finance and tax leaders are aware of clean energy tax credits, and we are seeing significant demand for high quality opportunities," said Reunion's CEO, Andy Moon. "We are thrilled to see corporations across many industries invest in transferable tax credits."
Reunion facilitates the purchase and sale of clean energy tax credits, and has worked with major corporations to purchase over $1.6 billion in tax credits from solar, wind, storage, advanced manufacturing, and other clean energy projects. Our curated marketplace features billions of dollars in high quality tax credit opportunities, and our team of clean energy finance veterans supports buyers and sellers through each step of the transaction process, with a focus on commercial negotiation, due diligence and risk mitigation.
Spotlight on the Inflation Reduction Act's Energy Community Bonus Credit Adder
The latest energy community guidance, which meaningfully expanded the number of qualifying areas, placed the 10% adder back in the spotlight for the transferable tax credit marketplace. At the same time, Reunion has observed a marked increase in the number of projects in our marketplace claiming the energy community bonus.
While our transferable tax credit handbook goes deep on energy communities, we wanted to share a comprehensive (and refreshed) look at the adder.
Our guide begins with the basics, so we invite you to jump ahead.
The Inflation Reduction Act created three bonus credits, or "adders"
The Inflation Reduction Act (IRA) created three "bonus" credits that can increase the value of a clean energy project's transferable tax credits:
Domestic content: 10% bonus
Energy community: 10% bonus
Low-income community: 10% or 20% bonus
The energy community adder provides a 10% bonus credit
The energy community bonus provides a 10% increase to a project's credit value if the underlying project is located in an energy community (and meets prevailing wage and apprenticeship requirements).
A utility-scale solar project, for instance, that meets PWA requirements would receive tax credits worth 30% of its eligible cost basis. If the same project is located in an energy community, it would receive tax credits worth 40% of its eligible basis.
The IRA defines three types of energy communities
To qualify for the energy community bonus, a project must be located in at least one of three energy community "categories."
Category 1: Brownfield
A brownfield site is defined in 42 U.S.C. § 9601(39)(A) as "real property, the expansion, redevelopment, or reuse of which may be complicated by the presence or potential presence of a hazardous substance, pollutant, or contaminant" (as defined under 42 U.S.C. § 9601), and includes certain "mine-scarred land" (as defined in 42 U.S.C. § 9601(39)(D)(ii)(III)). A Brownfield site does not include the categories of property described in 42 U.S.C. § 9601(39)(B).
Three types of sites qualify as a brownfield under a safe harbor:
Existing brownfield: Brownfields that are already tracked by a federal, state, territorial, or federally-recognized Indian tribal brownfields program. Many states, like Idaho and New York, have their own brownfields programs with supporting maps. A valid brownfield site could be tracked by a state program but not a federal program, and vice versa
Phase II assessment: A Phase II Assessment has been completed with respect to the site and such Phase II Assessment confirms the presence on the site of a hazardous substance as defined under 42 U.S.C. § 9601(14), or a pollutant or contaminant as defined under 42 U.S.C. § 9601(33)
Phase 1 assessment (for projects with a nameplate capacity of not greater than 5MWac): A Phase I Assessment has been completed with respect to the site and such Phase I Assessment identifies the presence or potential presence on the site of a hazardous substance, or a pollutant or contaminant.
Category 2: Coal closure
A census tract (or directly adjoining census tract):
in which a coal mine has closed after 1999; or
in which a coal-fired electric generating unit has been retired after 2009
Category 3: Statistical area
A "metropolitan statistical area" (MSA) or "non-metropolitan statistical area" (non-MSA) that has (or had at any time after 2009):
0.17% or greater direct employment or 25% or greater local tax revenues related to the extraction, processing, transport, or storage of coal, oil, or natural gas; and
has an unemployment rate or above the national average unemployment rate for the previous year
The scope of "direct employment" is determined by ten NAICS codes.
No double bonus for multiple energy communities
If a clean energy project is located in two energy communities – a brownfield site within a coal community, for instance – the bonus remains 10%. Developers cannot double up.
Bonus credits cannot be sold in stand-alone tranches
Bonus credits are not treated differently from base credits for the purpose of transferability. Treasury guidance released in June 2023 specified that all transferable credits must be sold as “vertical slices” and be pari passu to one another, as opposed to “horizontally” bifurcating bonus credits from base credits.
Green H4 Element
Credit and project eligibility
Four IRA credits are eligible for the energy community bonus
The IRA created 11 transferable tax credits, four of which are eligible for the energy community bonus:
§45 PTC: Electricity produced from certain renewable resources
§48 and §48E ITC eligibility determined on placed-in-service date
For projects that claim an investment tax credit under §48 or §48E, eligibility for the energy community bonus credit is determined on the date that the project is placed in service (PIS) and is not tested again.
Because eligibility is determined on a PIS date that is subject to potential delays, developers should think carefully about how to incorporate the statistical area category into their financial assumptions.
The statistical area category is determined annually, based on the prior year's unemployment rate. As the IRS FAQs state, "Because an MSA's or non-MSA's status as an energy community depends on its unemployment rate for the previous year, an MSA or non-MSA that qualifies as an energy community in one period might not qualify as an energy community in a later period if its unemployment rate for the previous year falls below the national average."
§45 and §45Y PTC eligibility determined annually with a beginning-of-construction safe harbor
For projects that claim a production tax credit under §45 or §45Y, eligibility for the energy community bonus credit must be determined every year during the ten-year PTC period. Theoretically, a wind project could qualify one year under the statistical area category but not qualify the following year because of a change in employment rates.
However, the IRS created a safe harbor for PTC projects with beginning-of-construction dates on or after January 1, 2023. If the project owner determines that the project is eligible for the energy community bonus credit on the date construction is considered to have started for tax purposes, then the project will qualify for the bonus credit for the entire ten-year PTC period and is not tested again.
"Legacy" §45 PTCs are not eligible for energy community bonus
Projects that generate §45 PTCs that were placed in service before December 31, 2022 are not eligible for the energy community bonus, even if the project happens to be located in an energy community and is within its ten-year period of credit generation.
The December 31, 2022 date is set in the IRA itself (H.R.5376).
50% of a project's nameplate capacity (or square footage) must be in an energy community
A project qualifies for the energy community bonus if at least half (50%) of its nameplate capacity is in an energy community. According to the IRS, nameplate capacity is the DC capacity that a project is capable of producing on a steady-state basis during continuous operation under standard conditions.
For battery storage projects, at least half (50%) of the storage capacity, as measured in megawatt hours, should be in an energy community.
Lastly, for projects that do not generate nor store energy, like biogas, the 50% threshold is measured on a square footage basis.
Green H4 Element
Diligence
When performing due diligence on the energy community bonus, it's helpful to approach the process based on the credit type and energy community category.
Credit type
ITCs
Tax credit buyers should request documentation that demonstrates when and where the project was placed in service. Then, buyers and their advisors should crosswalk that location to an appropriate energy community siting resource, like one of the IRS's appendices. (We provide links to these appendices in the guidance section of this post.)
When validating a project's location, it's important to keep the "50%" rule in mind.
PTCs
Due diligencing the energy community bonus for PTCs is effectively the same as ITCs, although buyers will want to validate when and where the project began construction (versus when and where the project was placed in service). Once again, it's important to keep the "50%" rule in mind.
Energy community category
As far as each category is concerned, the statistical area and coal closure categories are relatively straightforward from a due diligence standpoint: the IRS has published lists of areas that qualify for each. The brownfield category, however, may present a slightly more nuanced due diligence process.
Statistical area
It's important to recall that the statistical area category changes every year, based on the prior year's unemployment rate. As we'll discuss below, the IRS is obligated to publish updates to this category every year, generally in May.
Coal closure
Unlike the statistical area category, the coal closure category cannot shrink – that is, once an area qualifies as a coal closure, it remains as such for the duration of the energy community bonus.
The IRS has not published – and, as far as we know, has no plans to publish – a consolidated list of areas that qualify as brownfields for purposes of the energy community bonus. In fact, the DOE energy community map doesn't even include federally-recognized brownfield sites. (The EPA, however, maintains a list of federally-recognized brownfields in its cleanups in my community map.)
We doubt the IRS or any federal agency will publish a definitive list of brownfields. There are simply too many moving parts across federal, state, local, and tribal brownfields programs.
Latest guidance expands the number of areas that are eligible for the energy community bonus
The most recent IRS guidance, Notice 2024-30, broadened eligibility for the energy community bonus through two key changes:
Expansion of the "nameplate capacity attribution rule"
Inclusion of two additional NAICS codes – which are in our list above – for determining the fossil fuel employment rate for a statistical area category
Expansion of the nameplate capacity attribution rule
The "nameplate capacity attribution rule" pertains to projects with offshore generation – namely, offshore wind – that have a nameplate capacity but are not located within a census tract, an MSA, or a non-MSA. The rule, essentially, allows developers to allocate their offshore nameplate capacity onshore for purposes of qualifying for the energy community bonus.
Prior to Notice 2024-30, the attribution rule generally allowed offshore wind projects to qualify for the energy community bonus if their power-conditioning equipment closest to the point of interconnection was in an energy community.
Notice 2024-30 expanded the nameplate capacity attribution rule to include not only power-conditioning equipment, but also supervisory control and data acquisition (SCADA) equipment.
SCADA equipment must be owned by the developer and located in an "energy community project port." To qualify as an energy community project port, a port must:
Be used "either full or part-time to facilitate maritime operations necessary for the installation or operation and maintenance" of the project
Have a "significant long-term relationship" with the project, meaning the developer owns or leases all or part of the port for a minimum term of ten years
Be the location at which staff employed by, or working as independent contractors for, the project are based and perform functions essential to the project's operations. Essential functions include "management of marine operations, inventory and handling of spare parts and consumables, and berthing and dispatch of operation and maintenance vessels and associated crews and technicians"
Inclusion of two additional NAICS codes
Notice 2024-30 added two additional NAICS codes for determining the fossil fuel employment rate for a statistical area category:
2212: Natural gas distribution
23712: Oil and gas and pipeline and related structures construction
These NAICS codes cover workers in local gas distribution companies and construction workers on oil and gas pipelines.
According to Norton Rose Fulbright, "The biggest additions to the list of potentially eligible counties are in six Midwestern states: Minnesota (57), Missouri (57), Illinois (28), North Dakota (23), Wisconsin (23) and Indiana (20)."
The IRS has released five pieces of energy community guidance, with regulations to come soon
Energy community regulations should arrive by June 30, 2024
As Notice 2024-30 notes, proposed regulations are forthcoming. Until then, "taxpayers may rely on the rules described in sections 3 through 6 of Notice 2023-29, as previously clarified by Notice 2023-45 and modified by section 3 [of] this notice, for taxable years ending after April 4, 2023."
Based on the Q2 update to the IRS 2023-2024 Priority Guidance Plan, energy community regulations should arrive before the end of the current "plan year," which concludes on June 30, 2024.
Where to find the latest guidance
The IRS and Treasury maintain lists of IRA-related guidance, including guidance specific to the energy community adder. Although the lists generally overlap, there may be differences based on when each website was last updated.
Below is a close look at all the guidance that's been released through March 2024.
Notice 2022-51: Request for Comments on Prevailing Wage, Apprenticeship, Domestic Content, and Energy Communities Requirements under the Inflation Reduction Act of 2022
Annual updates to areas qualifying as energy communities
Expect energy community eligibility updates every May, beginning in 2024
According to Notice 2023-29, "The Treasury Department and the IRS intend to update the listing of the Statistical Area Category based on Fossil Fuel Employment annually. These updates generally will be issued annually in May."
DOE, EPA, and IRS have provided energy community eligibility and project siting resources
U.S. federal agencies who are responsible for administering or managing parts of the energy community bonus credit have published several key resources that are valuable to buyers, sellers, and their advisors:
Webinar Recording: Navigating the Tax Credit Transfer Process for Corporate Taxpayers
Recording
Overview
For corporate taxpayers who are considering purchasing tax credits in 2024, please join Reunion's transactions team – with 50+ years of combined experience in tax credits – for a 60-minute workshop to walk through a sample tax credit transfer.
The webinar will equip tax and treasury teams with the information and resources they need to efficiently pursue a tax credit transaction.
Topics
The interactive workshop will include three 15-minute modules and five minutes of Q&A per module.
Speakers
Reunion's CEO, Andy Moon, and President, Billy Lee, will co-host the webinar. Over the course of their careers in clean energy financing, Andy and Billy have executed over $2B in transactions across a range of technologies.