Tag: IRS

Year-End Estate Planning Update: Strategies for 2025

The 2025 transfer tax exemption will remain at a historically high level before being reduced by 50% on January 1, 2026 under current law. As it remains uncertain whether the new Congress will enact legislation to maintain the current exemption amount, taxpayers should continue planning with the current law in mind. There are a variety of strategies available to take advantage of current exemption levels.

Current Transfer Tax Laws

The federal gift/estate and generation-skipping transfer (GST) tax exemptions (i.e., the amount an individual can transfer free of such taxes) were $13.61 million per person in 2024 and will increase to an unprecedented $13.99 million in 2025. However, under current law these exemptions will be reduced by 50% on January 1, 2026 (but still inflation adjusted each year). While Congress may do nothing and maintain the current transfer tax laws (allowing the exemptions to be cut in half), or repeal the transfer taxes altogether, due to budgetary constraints, it is more likely that Congress will simply extend the timeframe for when the exemptions will be reduced, perhaps by two, four, or 10 years. The federal transfer tax exemptions can be used either during lifetime or at death. Using exemption during lifetime is generally more efficient for transfer tax purposes, as any appreciation on the gifted assets escapes estate taxation. The Illinois estate tax exemption remains at $4 million per person, as this exemption does not receive an annual inflationary increase.

For individuals concerned about estate taxation upon death, there are estate planning strategies available to utilize the current historically high exemptions. However, these strategies must also address the potential loss of a basis change on death. Estate taxes are imposed at a 40% federal rate on a decedent’s “taxable estate” not qualifying for a marital or charitable deduction, plus potential state estate taxes. In Illinois, the effective marginal tax rate ranges from 8% to approximately 29%. As with income taxes, state estate taxes are deductible for federal estate tax purposes, resulting in a cumulative federal and Illinois estate tax rate (for estates above both the federal and Illinois exemptions), taking deductions into account, of approximately 48%. The trade-off is the loss of the basis change at death (discussed below), which can result in an income tax cost on any “built in” gains aggregating 28.75% (a federal 20% capital gains tax, plus the 3.8% federal net investment income tax, plus state capital gains taxes of 4.95% in Illinois).

In 2025, a married couple can transfer up to $27.98 million free of federal transfer tax, but as discussed above, under current federal law, the estate/gift and GST tax exemptions are to be reduced by 50% in 2026. The Treasury Department has confirmed that the additional transfer tax exemption granted under current law until 2026 is a “use it or lose it” benefit, and that if a taxpayer uses the “extra” exemption before it expires (i.e., by making lifetime gifts), it will not be “clawed back” causing additional tax if the taxpayer dies after the exemption is reduced in 2026. This means that a taxpayer who has made $6.995 million or less (adjusted for inflation) of lifetime gifts before 2026 will not “lock in” any benefit of the extra exemption, while a taxpayer who makes use of the additional exemption before 2026 (e.g., by making gifts of $13.99 million before 2026) will “lock in” the benefit of the extra exemption.

Lifetime Transfer Strategies

In addition to making such annual exclusion gifts, taxpayers should strongly consider lifetime gifting strategies in 2025 in excess of those amounts. Taxpayers who have not used the “extra” exemption before January 2026 may lose it forever. Furthermore, any post-appreciation transfer on gifted assets accrues outside of the taxpayer’s estate. This is especially salient for younger individuals and for transfers of assets with high potential for appreciation. For taxpayers who live in states with a state estate tax but no state gift tax (such as Illinois), lifetime gifting will also have the effect of reducing the state estate tax liability.

New Rules for Required Minimum Distributions from Certain Inherited IRAs

The IRS issued new Final Regulations in 2024 that Required Minimum Distributions from certain retirement plans that beneficiaries must take to avoid penalties (hereinafter referred to as “inherited IRAs” even though they encompass all retirement plans). Congress enacted the SECURE Act in 2019, which set the current law for Required Minimum Distributions from inherited IRAs and other retirement plans. In general, other than a spouse, minor child of the decedent, or disabled child of the decedent for whom special “stretch rules” may apply, beneficiaries have a 10-year period within which all of the IRA funds have to be withdrawn to avoid penalties (no distributions until December 31 of the year in which the 10th anniversary of death falls). Based upon this rule, many beneficiaries intentionally planned to not withdraw IRA funds until the end of the 10-year period in order to let the funds grow income tax deferred (unless earlier distributions could be made at a lower income tax rate based upon their individual situation year by year). Effective for taxable years beginning on or after January 1, 2025, the IRS’s new Regulations change this 10-year rule for beneficiaries that inherited an IRA from a decedent that was passed his or her “required beginning date” (age 72 if the decedent was born in 1950 or before, age 73 if born 1951-1959, and age 75 if born 1960 or later). For such beneficiaries (the decedent dying past his or her required beginning date), the beneficiary is required to take annual distributions during the 10-year period based upon the beneficiary’s life expectancy and must drain whatever is left by December 31 of the 10th year after death. Failure to take the Required Minimum Distribution can result in significant penalties. This annual Required Minimum Distribution amount does not apply to spousal rollover IRAs, to IRAs for which the beneficiary qualified and was using a special life expectancy rule, to IRAs when the participant died before his or her required beginning date, or to IRAs inherited before 2020.

Planning for Basis Change

Good estate planning incorporates income tax and other considerations rather than focusing myopically on estate, gift, and GST taxes. In general, upon an individual’s death, the cost basis of any assets that are included in his or her gross estate for estate tax purposes receive an adjustment to their fair market value at the date of death. For appreciated assets, this can result in substantial income tax savings. Assets that are not included in the gross estate, however, do not receive a basis adjustment. Therefore, there is often a trade-off between making lifetime gifts (to reduce estate taxes, but with the donee receiving the donor’s “carry-over” basis) and keeping assets in the gross estate (to obtain the basis adjustment and reduce income taxes).

Fortunately, there are a number of techniques to help plan for possible change in basis while still retaining estate tax benefits. Irrevocable trusts that receive lifetime gifts can be structured to allow for a possible basis change. One way to do so is by including a broad distribution standard in the trust agreement by which an independent trustee can make distributions out of the trust to the beneficiary. Additionally, a trust can be structured to grant an independent trustee the power to grant (or not grant) the beneficiary a “general power of appointment,” which would cause the trust assets to be includible in the beneficiary’s estate for estate tax purposes and therefore receive the basis adjustment. Finally, if an irrevocable trust is structured as a grantor trust, the grantor can retain a “swap power” that can be used to transfer high-basis assets to the trust and take back low-basis assets, in order to obtain the largest possible “step up” in basis.

The Corporate Transparency Act

As of January 1, 2024, domestic and foreign entities created by filing with a Secretary of State or foreign entities registered to do business with a Secretary of State (i.e., corporations, LLCs, and limited partnerships), are required to report beneficial ownership information to the Financial Crimes Enforcement Network, subject to limited exemptions. “Reporting Companies” are required to report the full legal name, birthdate, residential address, and a unique identifying number from a passport or driver’s license (along with a copy of the passport or driver’s license) for any owner who directly or indirectly (i) owns at least 25% of the ownership interests or (ii) directly or indirectly exercises “substantial control” over the entity.

Entities in existence before January 1, 2024 have until December 31, 2024 to comply with the reporting requirement. Entities formed in 2024 have 90 days from the date of formation to comply with the reporting requirement. New entities formed on or after January 1, 2025 will have 30 days from formation to comply with the reporting requirement. There is also a supplemental filing requirement every time any information on the filed Report changes, due 30 days after each such change.

© 2024 Much Shelist, P.C.
For more on Estate Planning, visit the NLR Estates Trusts section

Disregarded Entity Eligibility for the CTA Large Operating Company Exemption

Summary: As discussed in detail below, the Corporate Transparency Act (CTA) provides an exemption to its reporting requirements for certain large operating companies (the Large Operating Company Exemption or “LOC Exemption”). In order to qualify for the LOC Exemption, a reporting company must, among other requirements, “have filed a Federal income tax or information return in the United States in the previous year demonstrating more than $5,000,000 in gross receipts or sales.” Certain reporting companies are “disregarded entities” (DREs) for Federal tax purposes and, as such, do not themselves directly have a Federal tax filing obligation or ability. However, based upon guidance from FinCEN and the IRS, support exists for the proposition that the Federal tax filing of a DRE’s sole individual owner or sole parent entity constitutes the filing referenced in the LOC Exemption, and that a DRE reporting company is not, per se, disqualified from utilizing the LOC Exemption.

* * * * *

Certain business entities may elect (including through default attribution under the Internal Revenue Code, (IRC) to be treated as “disregarded” from their individual owner or parent entity for U.S. federal income tax purposes. Such entities include limited liability companies (LLCs) who have a single member (unless such an LLC has elected on Internal Revenue Service (IRS) Form 8832 to be taxed as a “corporation”), or certain wholly owned subsidiaries of “S-corporations” where the parent S-corporation has made an election (referred to as a “Q-Sub election”) on IRS Form 8869 to treat the subsidiary as a qualified subchapter S subsidiary (QSub), whereby such Q-Sub is deemed to be liquidated (for federal tax purposes only) into the parent S-corporation.

These entities, often referred to simply as “disregarded entities” do not, as a distinct, juridical person, file a federal income tax return per se. Instead, DREs have their taxable income and loss reflected, on an aggregated basis, on the federal income tax return of their individual owner or (direct or indirect) parent entity. In fact, when reporting the taxpayer identification number (TIN) of a DRE on an IRS Form W-9 (Request for Taxpayer Identification Number and Certification), the DRE provides the federal employer identification number (FEIN) of a parent entity or a social security number (SSN) of an individual owner, rather than a TIN of the DRE itself. This is true even if the DRE has filed for, and has received from the IRS, its own FEIN.

Further to this point, some DREs do not, and are not required to, file for their own FEIN. As such, not all DREs possess their own FEIN or other entity distinct TIN.

The Financial Crimes Enforcement Network (FinCEN), in its Frequently Asked Question F.13 issued July 24, 2024, acknowledged this fact as follows:

“An entity that is disregarded for U.S. tax purposes—a “disregarded entity”—is not treated as an entity separate from its owner for U.S. tax purposes. Instead of a disregarded entity being taxed separately, the entity’s owner reports the entity’s income and deductions as part of the owner’s federal tax return. …

Consistent with rules of the Internal Revenue Service (IRS) regarding the use of TINs, different types of tax identification numbers may be reported for disregarded entities under different circumstances:

  • If the disregarded entity has its own EIN, it may report that EIN as its TIN. If the disregarded entity does not have an EIN, it is not required to obtain one to meet its BOI reporting requirements so long as it can instead provide another type of TIN….
  • If the disregarded entity is a single-member limited liability company (LLC) or otherwise has only one owner that is an individual with a SSN or ITIN, the disregarded entity may report that individual’s SSN or ITIN as its TIN.
  • If the disregarded entity is owned by a U.S. entity that has an EIN, the disregarded entity may report that other entity’s EIN as its TIN.
  • If the disregarded entity is owned by another disregarded entity or a chain of disregarded entities, the disregarded entity may report the TIN of the first owner up the chain of disregarded entities that has a TIN as its TIN.

As explained above, a disregarded entity that is a reporting company must report one of these tax identification numbers when reporting beneficial ownership information to FinCEN.”i

While the above FAQ is not offered by FinCEN specifically in the context of the LOC Exemption, this FAQ does have important implications for the LOC Exemption. In stating that a DRE is not required to obtain an FEIN merely for purposes of having such a number for purposes of filing a beneficial ownership information report (BOIR) under the CTA, and acknowledging that a DRE may provide a SSN of an individual owner, or an FEIN of a parent entity, in satisfaction of the DRE’s requirement to provide a tax identification number as required in FinCEN’s form for filing BOIRs, FinCEN has recognized that the same TIN required by the IRS to be disclosed on a Form W-9 in respect of a DRE is recognized by FinCEN as an appropriate TIN in respect of the DRE for purposes of such entity’s BOIR filing.

As such, the federal tax return filing associated with such a TIN is, therefore, the tax return associated with the DRE reporting such TIN on its BOIR filing. In other words, the fact that an individual owner or a parent entity has made a prior year’s federal tax return filing, which filing includes the U.S. generated gross receipts or sales of the DRE, should be sufficient to satisfy the DRE’s prior year’s federal tax return filing status with respect to such revenue.

As stated in FAQ F.13 above, “a DRE—is not treated as an entity separate from its owner for U.S. tax purposes…, the entity’s owner reports the entity’s income and deductions as part of the owner’s federal tax return…”

* * * * *

With this background, we next analyze the associated implications to a DRE that may qualify for the LOC Exemption.

For purposes of clarity, the requirements for an entity to qualify for the LOC Exemption is that the entity satisfy all three parts of the following three-part test:

“[A]n entity must have more than 20 full-time employees in the United States, must have filed a Federal income tax or information return in the United States in the previous year demonstrating more than $5,000,000 in gross receipts or sales, and must have an operating presence at a physical office in the United States.”ii

The CTA itself provides more specificity in this regard. The CTA provides that the term “reporting company” does not include any entity that:

“(I) employs more than 20 employees on a full-time basis in the United States; (II) filed in the previous year Federal income tax returns in the United States demonstrating more than $5,000,000 in gross receipts or sales in the aggregate, including the receipts or sales of (aa) other entities owned by the entity; and (bb) other entities through which the entity operates; and (III) has an operating presence at a physical office within the United States.”iii

Although FinCEN has, to date, issued no formal acknowledgment or interpretation with regard to the applicability of the above “revenue prong” specifically in the DRE context, for the reasons outlined above, a reasoned and supported proposition in the DRE situation may be that the “filed Federal income tax or information return” referenced in the LOC Exemption is the federal tax return filing of the reporting company’s individual owner or parent entity, as applicable.

Further to the revenue prong, it appears that if the DRE itself generates U.S. generated gross receipts or sales in excess of five million dollars as reported on the prior year’s federal tax return filing, that the DRE meets the revenue prong of the LOC Exemption. However, based on the above analysis, it may also be a colorable position that the DRE MAY be able to assert that ALL of the U.S. generated gross revenue appearing on the individual owner’s or parent entity’s federal tax return filing may be attributable to the revenue test prong of the LOC Exemption, because all of such revenue is associated with that tax return. This situation is notionally similar to FinCEN’s interpretation that all members of a consolidated corporate taxed group (including each subsidiary) may share in credit for the aggregated gross receipts or sales of the entire group in meeting each of their respective, individual revenue requirements under the LOC Exemption. Here, both the individual and DRE or the parent entity and disregarded subsidiary would be relying upon the same federal tax return, in the individual or partnership tax context.

* * * * *

For purposes of clarity and completeness, we acknowledge a countervailing position espoused by some commentators in the marketplace. That position holds that a DRE is ab initio ineligible to qualify for the LOC Exemption merely because of such reporting company’s status as a DRE (i.e., that it, itself, as a business entity, does not directly cause the filing of its own, independent federal tax return). For the reasons outlined herein, we find this position less compelling than the proposition that disregarded entities have a filed Federal income tax or information return when filed by their individual owner or parent entity.

* * * * *

With respect to exemptions from the reporting obligations under the CTA, each such exemption is “self-executing.” In other words, if an exemption applies to a reporting company, that reporting company has no filing obligation to FinCEN under the CTA. As such, there is no BOIR filing on record documenting that the DRE is relying on its individual owner’s SSN or its parent entity’s FEIN, and, derivatively, the associated federal tax return filing, in establishing compliance with the revenue prong of the LOC Exemption test. We recommend that each DRE making such a reliance-based exemption determination maintain a record of their CTA diligence, analysis and exercise of business judgment made upon a fully informed basis, that underpins the substantiation of the DRE’s satisfaction of all parts of the LOC Exemption test.iv Such substantiation may be needed in the future if FinCEN or one of the DRE’s financial institutions requests substantiation of the DRE’s asserted position that such DRE is not required to file a BOIR under the CTA.

* * * * *

Conclusion. The compliance requirements under the CTA went live on January 1, 2024, and you have only the remainder of this year to take any action to prepare for your compliance position. Now is the time to discuss the CTA with your Polsinelli legal team for guidance.

[i] See FinCEN CTA FAQs F.13 (issued July 24, 2024)(https://www.fincen.gov/boi-faqs)

[ii] See FinCEN CTA FAQs L.7 (issued April 18, 2024)(https://www.fincen.gov/boi-faqs)

[iii] U.S.C. § 5336 (a)(11)(B)(xxi).

[iv] Note that there are other factors of the LOC Exemption that must be met in order to rely on that exemption, and such other factors are required to be met directly by the DRE. This discussion is not intended to suggest that the DRE may rely, for example, on employee counts of affiliated entities or impermissible U.S. physical address locations in qualifying for the LOC Exemption.

© Polsinelli PC, Polsinelli LLP in California
For more on the Corporate Transparency Act, visit the NLR Corporate Business Organizations section

IRS Announces 2025 Retirement Plan Limits

The Internal Revenue Service (“IRS”) has announced the following dollar limits applicable to tax-qualified plans for 2025:

  • The limit on the maximum amount of elective contributions that a person may make to a 401(k) plan, a 403(b) tax-sheltered annuity, or a 457(b) eligible deferred compensation plan increased from $23,000 to $23,500.
  • The limit on “catch-up contributions” to a 401(k) plan, a 403(b) tax-sheltered annuity, or a 457(b) eligible deferred compensation plan for persons age 50 and older is unchanged for 2025 at $7,500.
  • As a result of change made by SECURE 2.0, for 2025, employees aged 60, 61, 62, and 63 who participate in a 401(k) plan, a 403(b) tax-sheltered annuity, or a 457(b) eligible deferred compensation have a higher catch-up contribution limit, which for 2025 is $11,250 instead of $7,500.
  • The dollar limit on the maximum permissible allocation under 401(k) and other defined contribution plans is increased from $69,000 to $70,000.
  • The maximum annual benefit under a defined benefit plan is increased from $275,000 to $280,000.
  • The maximum amount of annual compensation that may be taken into account on behalf of any participant under a qualified plan will go from $345,000 to $350,000.
  • The dollar amount used to identify “highly compensated employees” is increased from $155,000 to $160,000.

Additional information regarding benefit plan dollar limits can be obtained in Notice 2024-80, 2025 Amounts Relating to Retirement Plans and IRAs, as Adjusted for Changes in Cost-of-Living.

© 2024 Blank Rome LLP
For more on the IRS, visit the NLR Tax section

2025 Inflation-Adjusted Plan Limits

On Nov. 1, 2024, the IRS published its annual cost of living adjustments for various retirement plan limits. These increases are more modest than recent years, a reflection that inflation is slowing. The updated key retirement plan limits include the following items:

2025 Limit 2024 Limit
Annual Compensation Limit $350,000 $345,000
Elective Deferral Limit $23,500 $23,000
Standard Age 50 Catch-Up Contribution Limit $7,500 $7,500
Age 60-63 Special Catch-Up Contribution Limit* $11,250 N/A
DC Maximum Contribution Limit $70,000 $69,000
DB Maximum Benefit Limit $280,000 $275,000
HCE Threshold $160,000 $155,000

*Note, this is a new provision under the SECURE 2.0 Act.

The IRS previously released the updated 2025 limits applicable to certain health and welfare plans, including the following key limits:

2025 Limit 2024 Limit
Health FSA – Maximum contributions $3,300 $3,200
Health FSA – Maximum carryover of unused amounts (optional plan provision) $660 $640
HSA – maximum contributions $4,300 (self-only)

$8,550 (family)

 $4,150 (self-only)

$8,300 (family)
HDHP – Minimum Deductible $1,650 (self-only)

$3,300 (family)

 $1,600 (self-only)

$3,200 (family)
HDHP – Maximum Out of Pocket $8,300 (self-only)

$16,600 (family)

 $8,050 (self-only)

$16,100 (family)
© 2024 Miller, Canfield, Paddock and Stone PLC
For more on Plan Limits, visit the NLR Estates Trusts section.

IRS Issues FAQs Regarding Long-Term Part-Time Employees in 403(b) Plans

The IRS recently issued Notice 2024-73, which provides much-needed guidance on long-term, part-time (“LTPT”) employees in ERISA-governed 403(b) retirement plans. Following passage of the SECURE 2.0 Act, an employee is generally considered a LTPT employee if he or she works at least 500 hours per year for two consecutive years.

Among other items, the Notice sets forth the IRS position on the following key issues on which the benefits community has been seeking clarification:

  • A part-time employee who qualifies as a LTPT employee must have the right to make elective deferrals to an ERISA 403(b) plan (unless some other statutory exemption applies), notwithstanding the Tax Code’s permitted exclusion for employees who normally work less than 20 hours per week.
  • An ERISA 403(b) plan may continue to exclude from the plan part-time employees who do not qualify as LTPT employees, notwithstanding the “consistency requirement,” which generally prevents a plan from excluding some part-time employees and not others.
  • An ERISA 403(b) plan is not required to provide the right to make elective deferrals to certain student employees, even if they qualify as LTPT employees. This is because the student employee exclusion is based on an employee classification (a student performing the service), rather than an amount of service (not an hours-based exclusion).

The guidance in the Notice is effective for plan years beginning after December 31, 2024. Importantly, the Notice also provides that a previously promulgated proposed regulation relating to the handling of LTPT employees in 401(k) plans, once finalized, will apply no earlier than plan years beginning on or after January 1, 2026 (i.e., a two-year extension).

© 2024 Miller, Canfield, Paddock and Stone PLC
For more on Long-Term Part-Time Employees, visit the NLR Labor Employment section.

Energy Tax Credits for a New World Part VII: Low-Income Communities Bonus Credits

What is the Low-Income Communities Bonus Credit?

The Low-Income Communities Bonus Credit available through the Inflation Reduction Act of 2022 (IRA)[1] is designed to increase the siting of, and access to renewable energy facilities in low-income communities, encourage new market participants, and provide social and economic benefits to individuals and communities that have been historically overburdened with pollution, adverse health or environmental effects, and marginalized from economic opportunities.[2]

The Low-Income Communities Bonus Credit supports “a transformative set of investments designed to create jobs, lower costs for American families, and spur an economic revitalization in communities that have historically been left behind.”[3] With the Low-Income Communities Bonus Credit the U.S. government is helping to “lower energy costs and provide breathing room for hard-working families, invest in good-paying clean energy jobs in low-income communities, and support small business growth.”[4]

The Low-Income Communities Bonus Credit is an investment tax credit (ITC) available for certain clean energy investments in low-income communities, on Indian lands, with certain affordable housing developments, and for certain projects benefiting low-income households.[5] It is an ITC for certain clean energy investments in a “Qualified Solar or Wind Facility,” that is, a facility with a net output of less than five megawatts. Unlike most of the other tax credits we have looked at in this Q&A with Andie series, there is a competitive bidding application process. Projects must receive a “Capacity Limitation Allocation Amount” to receive these credits.

What are the eligibility categories for the Low-Income Communities Bonus Credit?

There are four project eligibility criteria to qualify for the Low-Income Communities Bonus Credit:

  1. It is located in a “low-income community” (Category 1)
  2. It is located on “tribal Indian land” (Category 2)
  3. It is installed on certain federal housing projects that are qualified low-income residential building facilities (Category 3)
  4. It serves low-income households as a “qualified low-income economic project” (Category 4)

These eligibility categories are discussed in what follows.

Which tax credits do Low-Income Communities Bonus Credits apply to?

The Low-income Communities Bonus Credit is an additional bonus credit available for ITC-eligible credits at Internal Revenue Code (Code) Section 48, Energy Property ITC, and Section 48E, Clean Energy ITC (CEITC). Section 48 applies to an “eligible facility” (that is, a qualified solar or wind energy facility) for which construction begins before 2025; while the CEITC applies to construction in qualifying clean electricity generating facilities and energy storage technologies that are placed in service after December 31, 2024.[6] The base credit may be increased by 10 percent (for a project located in a low-income community or on Indian land) or by 20 percent (for a qualified low-income residential building project or a qualified low-income economic benefit project).[7]

Because the Section 48 credit expires at the end of 2024 and the Section 48E (CEIT) becomes effective January 1, 2025, we will need to look at Section 48 separately from Section 48E (CEITC) when we address the allocation procedures.

How is the Low-Income Communities Bonus Credit calculated?

The Low-Income Communities Bonus Credit is one of the few IRA energy tax credits that requires an application process and the granting of a “capacity limitation allocation amount.” For allocations in 2023 and 2024, the Section 48(e) ITC provides an increased tax credit for an eligible facility that is part of a “qualified solar or wind energy facility” and that receives a capacity limitation allocation amount. For allocations in 2025 and thereafter, the Section 48E (CEITC) credit applies to a broader group of facilities than those covered under Section 48(e).[8] For both Section 48 and 48E (CEITC), the base credit amount is six percent of a qualified investment (that is, the tax basis of the energy property), and that amount can be increased by 10- or 20-percentage points with the Low-Income Communities Bonus Credit, depending on whether the project meets certain eligibility category requirements.[9] The 10 percent credit is available for an eligible facility in a low-income community or on Indian land, while the 20 percent credit is available for a “qualified low-income residential building project” or a “qualified low-income economic benefit project.”

What is a qualified solar or wind facility?

A Qualified Solar or Wind Facility is an eligible facility if it meets three requirements.[10] First, it generates electricity solely from a wind facility, solar energy property, or small wind energy property. Second, it has a maximum net output of less than five megawatts as measured in alternating current. And third, it is described in at least one of the four Low-Income Communities Bonus Credit project categories.[11]

Because the eligible facility must have a maximum net output of less than five megawatts as measured in alternating current, can applicants divide larger projects into smaller ones to meet the five megawatts requirements?

No. The Treasury has issued Final Regulations on Low-Income Communities Bonus Credit (Final Low-Income Communities Regulations),[12] effective August 15, 2023. The Final Low-Income Communities Regulations provide that the capacity limitation allocation amounts will be made on a “single project factors test.”[13] This is intended to prevent applicants from artificially dividing larger projects into multiple facilities in an attempt to circumvent the requirement for the maximum net output.[14]

When can a Qualified Solar or Wind Facility be placed in service?

A project cannot be placed in service until after it receives the capacity allocation.[15] This is because the Treasury holds that “requiring projects to be placed in service after allocation provides the best way to promote the increase of, and access to, renewable energy facilities that would not be completed in the absence of the program.”[16] This is not viewed as an impediment because Section 48(e)(4)(E)(i) provides a “lengthy window of four years to place a facility in service following an Allocation of Capacity Limitation.”[17] Section 48E (CEITC) also provides a four-year window to place the facility in service.[18]

Definitions

What is a Category 1 low-income community for purposes of the Low-Income Communities Bonus Credit?

A Category 1 low-income community is a community that is located in a census area where the poverty rate is at least 20 percent or more, or the median family income is 80 percent or less than the median family income in the state where the community is located.[19] If the census tract is in a metropolitan area, the median family income cannot be more than 80 percent of the statewide median family income or the metropolitan area’s median family income.

The poverty rate for an eligible Category 1 low-income census tract is generally based on the threshold for low-income communities set by the New Markets Tax Credit (NMTC) Program, as noted in the Treasury Regulations. The NMTC updates its eligibility data every five years based on poverty estimates from the American Community Survey (ACS). New eligibility tables and maps for the NMTC program were released on September 1, 2023, which use underlying ACS estimates from 2016 to 2020.[20] The next NMTC update will include ACS estimates from 2021 to 2025, at which point applicants will have a period of one year following the date that the 2021-2025 NMTC is released to use the 2016-2020 NMTC dataset.[21]

How is Category 2 tribal Indian land defined?

Category 2 Tribal Indian land is land of “any Indian tribe, band, nation, or other organized group or community that is recognized as eligible for the special programs and services provided by the United States to tribes (Indians) because of their status.”[22] To qualify as Indian land, the property must meet the definition of Section 2601(2) of the Energy Policy Act of 1992, which is defined as, “Indian reservations; public domain Indian allotments; former Indian reservations in Oklahoma; land held by incorporated Native groups, regional corporations, and village corporations under the provisions of the Alaska Native Claims Settlement Act[23]; and dependent Indian communities within the borders of the United States whether within the original or subsequently acquired territory thereof, and whether within or without the limits of a State.”[24]

The Energy Policy Act of 1992 was amended by the Energy Act of 2020 to include in the definition of land occupied by a majority of Alaskan Native Tribe members.[25]

How is a Category 3 qualified low-income residential building project defined?

A Category 3 qualified low-income residential building project is a federally subsidized residential building facility “installed on the same parcel or on an adjacent parcel of land that has a residential rental building that participates in an affordable housing program, and the financial benefits of the electricity produced by such facilities are allocated equitably among the occupants of the dwelling units or the building.”[26] Projects must be part of a “qualified program”: one among various federal housing assistance programs as are set out in the Treasury Regulations. For state programs to qualify to receive the 20 percent bonus credit, they must be part of a qualified federal program. To remain a qualified low-income residential building facility, a project must maintain its participation in a covered housing program for the entire five-year tax credit recapture period.

How does a Category 4 qualified low-income economic benefit project assist low-income households?

A qualified low-income economic benefit project is one where at least 50 percent of the financial benefits of the electricity produced are provided to households with income of less than 200 percent of the poverty line, or 80 percent of the area’s median gross income.[27] The financial benefits of a low-income economic project benefiting low-income households can only be delivered in utility bills savings. “Other means such as gift cards, direct payments, or checks are not permissible. Financial benefits for these facilities must be tied to a utility bill of a qualifying household. The Treasury Department and the IRS may consider other methods of determining Category 4 financial benefits in future years.”[28]

Allocation Process

How is the annual Capacity Limitation allocated across the four facility categories?

The annual Capacity Limitation amount is divided across each facility category as is set out in each program year. For the 2023 and 2024 Program Years, for example, we have IRS Notices setting out the Allocation Process. The Applicable Bonus Credit is available at Section 48. For the calendar year 2025 and succeeding years, the applicable bonus credit is available at Section 48E (CEITC). On September 3, 2024, the Treasury issued Proposed Regulations addressing Section 48E (CEITC) (Proposed 48E Allocation Regulations).[29]

For the 2024 Program Year, for example, the annual Capacity Limitation is divided across each facility category “plus any carried over unallocated Capacity Limitation from the 2023 Program Year.”[30]

 Does the Low-Income Communities Bonus Credit have a competitive bidding application?

Yes. The Low-Income Communities Bonus Credit has a competitive bidding application process that applies to each of the four eligibility categories. An annual allocation of up to 1.8 gigawatts (GWs) is available, in the aggregate, to the four categories of qualified solar or wind facilities with a maximum output of less than five megawatts.[32]

How does competitive bidding work?

Since it was introduced for the 2023 program year, competitive bidding has been very successful. The Low-Income Communities Bonus Credit program is extremely popular. The 2023 program—the first year of the competitive bidding process—was significantly over-subscribed with more than 46,000 applications submitted. Applications were for qualified facilities representing 8 GWs of capacity, although only 1.8 GWs of capacity were available for allocation.[33]

For purposes of the Section 48E Low-Income Communities Bonus Credit, we have the Proposed Section 48E Regulations to turn to as to how the competitive bidding process works. The Treasury has provided notice of a public hearing on the Proposed Regulations for October 17, 2024.

What government guidance do we have on the annual Capacity Limitation allocation process for Section 48?

For purposes of the Section 48 Low-Income Communities Bonus Credit, we have the Final Low-Income Communities Regulations. In addition, the IRS has issued revenue procedures and a Notice:

  • Rev. Proc. 2023-27[34] and Rev. Proc. 2024-19[35] provide information and guidance for the 2023 and the 2024 allocations. These revenue procedures both address the reservation of capacity limitations, allocation selection, and application procedures.
  • IRS Notice 2023-17,[36] sets out initial guidance on establishing the program to allocate the environmental justice solar and wind capacity limitation under Section 48(e).

What does the 2024 allocation program look like?

The 2024 capacity limitation allocation opened in May of 2024, with 1.8 GWs of capacity being allocated across the four eligible facility type categories.[37]

Are there any additional selection criteria for 2024?

Yes. For 2024, the Treasury has imposed what it refers to as “additional selection criteria” (ASC) for the 1.8 GWs allocation. The 2024 ASC requires at least 50 percent of the 1.8 GWs to be allocated to applications that meet specified ASC ownership and geographic criteria.

The 2024 ASC ownership criteria is based on applicants that qualify as one of the following: Tribal enterprises, Alaska Native Corporations, renewable energy cooperatives, qualified renewable energy companies, qualified tax-exempt entities,[38] Indian tribal governments, and any corporation described in Section 501(c)(12) that furnishes electricity to persons in rural areas.

The 2024 geographic criteria is based on the facility being located in a persistent poverty county or disadvantaged community as identified by the Climate and Economic Justice Screening Tool.[39] The screening tool is at an official U.S. government website, with an interactive map of census tracts that are “overburdened and underserved” and that are “highlighted as being disadvantaged.[40] For these purposes, Alaska Native Villages are considered to be disadvantaged communities.[41] The datasets used in the Screening Tool’s eight “indicators of burdens” are “climate change, energy, health, housing, legacy pollution, transportation, water and wastewater, and workforce development.”[42]

Where do we look for 2025 allocations and beyond?

The selection criteria for 2025 and beyond is addressed in the Proposed Section 48E Regulations.

Application Process

How are applications reviewed and Capacity Limitations allocated?

The Treasury and the IRS have partnered with the DOE to administer the program. The DOE’s “Office of Economic Impact and Diversity administers the program application portal and reviews applications, with the DOE making “recommendations to the IRS” based on the eligibility of the facility.[43] The Treasury and the IRS can adjust the allocations of Capacity in future years “for categories that are oversubscribed or have excess capacity.”[44] “At least 50% of the capacity within each category will be reserved for projects that meet certain ownership and/or geographic selection criteria. The ownership and geographic selection criteria can be found in §1.48(e)-1(h)(2).”[45]

How does an applicant apply for the Low-Income Communities Bonus Credit Program?

A taxpayer seeking to claim the credit must submit an application to the DOE for an allocation of capacity. The DOE allows one application per project. To begin their process, an applicant must create a login.gov account and register using the “Log In” button located at a DOE’s portal page, https://eco.energy.gov/ejbonus/s/. Before registering, applicants are encouraged to read the handy dandy “DOE Applicant User Guide”[46] available at the same web portal address. Applications are submitted through DOE’s online “Low-Income Communities Bonus Credit Program Applicant Portal” accessible at the same URL. The portal’s applicant checklist sets out rigorous documentation and attestation requirements to demonstrate that ownership requirements are being met.

How does an applicant support its allocation of capacity for its Low-Income Communities Bonus Credit application?

An applicant must submit information for each proposed facility allocation, including the “applicable category, ownership, location, facility size/capacity, whether the applicant or facility meet additional selection criteria, and other information.”[47] In addition, the applicant must complete a series of attestations and must upload to the online portal certain documentation in order to demonstrate project maturity.”[48] An allocation must be received by the taxpayer before an eligible facility can be placed in service.[49]

How are applications considered?

“There will be a 30-day period at the start of each program year where applications will be accepted for each category. Applications received within this 30-day period will all be treated as being received on the same day and time. Once the 30-day period is over, the DOE will accept applications on a rolling basis and recommend applicants to the IRS until the entire capacity limitation within the applicable category is diminished.”[50] In addition, once applications are submitted, “the DOE will review the applications and recommend projects eligible for the bonus to the IRS. The IRS will then award the applicant with an allocation of the capacity limitation or reject the application. The DOE will stop reviewing applications once the entire capacity limitation is awarded. Applicants can reapply for the bonus credit in the next program year if they remain eligible.”[51]

What happens if a facility is not placed in service within the four-year deadline?

A facility can be disqualified after it receives an allocation if the facility is not placed in service within the deadline set in Section 48(e)(4)(E) of four years after the date of allocation. “[P]roviding any type of alternative forms of completion within the four year window apart from ‘placed-in-service’ is inconsistent with the statute and not allowed.”[52]

Can a credit recipient face a recapture event?

Yes. Recapture of the benefit of any increased credit due to Section 48E is provided in Section 48(e)(5). The Treasury noted that “Under the recapture provisions of Section 48(e)(5), Congress provided that the period and percentage of such recapture must be determined under rules similar to the rules of Section 50(a). Section 50(a) generally provides that this is a five year period with differing applicable percentages depending on when the property ceases to qualify. Therefore, under Section 48(e)(5), stricter restrictions related to recapture should not be imposed.”[53]

The final regulations clarify that “any event that results in recapture under Section 50(a) will also result in recapture of the benefit of the section 48(e) Increase. The exception to the application of recapture provided in § 1.48(e)-1(n)(2) does not apply in the case of a recapture event under Section 50(a).”[54] This same recapture possibility applies to Section 48E (CEITC) credit recipients.

The firm extends gratitude to Nicholas C. Mowbray for his comments and exceptional assistance in the preparation of this article.

[1] The Inflation Reduction Act of 2022, Pub. L. No. 117-169, 136 Stat. 1818 (2022) (IRA), August 16, 2022.

[2] “Inflation Reduction Act Guide for Local Governments and Other Tax-Exempt Entities; Solar and Storage Projects,” p. 17, New York State, January 2024, available at https://www.nyserda.ny.gov/-/media/Project/Nyserda/Files/Programs/Clean-Energy-Siting/Inflation-Reduction-Act-Guide-for-Solar-and-Storage-Projects.pdf.

[3] “Low-Income Communities Bonus Credit Program,” Department of Energy (DOE), Office of Energy Justice and Equity, available at https://www.energy.gov/justice/low-income-communities-bonus-credit-program.

[4] “U.S. Department of the Treasury, IRS Release Final Rules and Guidance on Investing in America Program to Spur Clean Energy Investments in Underserved Communities,” Press Release, U.S. Treasury, August 10, 2023, available at https://home.treasury.gov/news/press-releases/jy1688.

[5] “Low-Income Communities Bonus Credit,” IRS, available at https://www.irs.gov/credits-deductions/low-income-communities-bonus-credit.

[6] For a discussion of Sections 48 and 48E (CEITC), see Part II of this series: Production Tax Credits and Investment Tax Credits: The Old and The New.

[7] § 48(e).

[8] § 48E(h). “Elective pay and transferability frequently asked questions: Elective pay,” IRS, Overview, Q15, available at https://www.irs.gov/credits-deductions/elective-pay-and-transferability-frequently-asked-questions-elective-pay#q15.

[9] § 48(e)(1).

[10] Section 48(e)(2)(A) and the Treasury Regulations.

[11] Section 48(e)(2)(A)(iii).

[12] 88 FR 55506, “Additional Guidance on Low-Income Communities Bonus Credit Program,” U.S. Treasury, August 15, 2023, available at https://www.federalregister.gov/documents/2023/08/15/2023-17078/additional-guidance-on-low-income-communities-bonus-credit-program.

[13] Ibid.

[14] Ibid, Preamble, Definition of Qualified Solar or Wind Facility.

[15] 88 FR 55506, August 15, 2023.

[16] Ibid.

[17] Ibid.

[18] Ibid.

[19] “Inflation Reduction Act Guide for Local Governments and Other Tax-Exempt Entities; Solar and Storage Projects,” p. 18, New York State, January 2024.

[20] “Frequently Asked Questions, 48(e) Low-Income Communities Bonus Credit Program,” Q47.

[21] Ibid.

[22] Ibid.

[23] 43 U.S.C. § 1601 et seq.

[24] 106 Stat. 3113; 25 U.S.C. § 3501.

[25] The Energy Act of 2020, Section 8013, As Amended Through Pub. L. 117-286, Enacted December 27, 2022. See also “Energy Act of 2020, Section-by-Section,” Section 8013. Indian Energy, available at https://www.energy.senate.gov/services/files/32B4E9F4-F13A-44F6-A0CA-E10B3392D47A.

[26] “Inflation Reduction Act Guide for Local Governments and Other Tax-Exempt Entities; Solar and Storage Projects,” p. 18, New York State, January 2024.

[27] Ibid.

[28] FAQ#53.

[29] 89 Fed. Reg. 71193 (Sept. 3, 2024).

[30] “Low-Income Communities Bonus Credit Program,” DOE, Office of Energy Justice and Equity, available at https://www.energy.gov/justice/low-income-communities-bonus-credit-program. Also see https://www.energy.gov/sites/default/files/2024-05/48e%20Slides%20for%20PY24%20Applicant%20Webinar.pdf and refer to Rev. Proc. 2024-19 (IRS) and Treasury Regulations § 1.48(e)–1 for the full definitions and requirements of each program category.

[31] Such as rooftop solar.

[32] “U.S. Department of the Treasury, IRS Release 2024 Guidance for Second Year of Program to Spur Clean Energy Investments in Underserved Communities, As Part of Investing in America Agenda,” Press Release, U.S Treasury, March 29, 2024. Proposed Section 48E (CEITC) Regulations.

[33] “The Low-Income Communities Bonus Credit Program: Categories and How to Apply,” Morgan Mahaffey, EisnerAmper, May 29, 2024, available at https://www.eisneramper.com/insights/real-estate/low-income-communities-bonus-credit-program-0524/

[34] Rev. Proc. 2023-27, IRS, August 10, 2023, corrected by Announcement 2023-28, September 11, 2023.

[35] Rev. Proc. 2024-19, IRS, March 29, 2024.

[36] Notice 2023-17, IRS, February 13, 2023.

[37] Treas. Reg. §1.48(e)-1 defines the four categories of facilities for Low-Income Communities Bonus Credit.

[38] Including Sections 501(c)(3) and 501(d) entities.

[39] The screening tool is available at https://screeningtool.geoplatform.gov/en/#3/33.47/-97.5.

[40] Ibid.

[41] Ibid.

[42] Climate and Economic Justice Screening Tool, Frequently Asked Questions, available at https://screeningtool.geoplatform.gov/en/frequently-asked-questions#3/31.77/-95.39.

[43] Ibid.

[44] “IRS releases Guidance on Low-Income Communities Bonus Credit Program, Inflation Reduction Act,” Forvis Mazars, LLP, August 15, 2023, available at https://www.forvismazars.us/forsights/2023/08/irs-releases-guidance-on-low-income-communities-bonus-credit-program.

[45] Ibid. See also, § 1.48(e)-1(h)(2), the Reservations of Capacity Limitation allocation for facilities that meet certain additional selection criteria is available at https://www.law.cornell.edu/cfr/text/26/1.48(e)-1.

[46] “Applicant User Guide,” DOE, available at https://www.energy.gov/sites/default/files/2024-05/2024%20DOE%2048%28e%29%20Applicant%20User%20Guide.pdf.

[47] “Low-Income Communities Bonus Credit Program,” DOE, Office of Energy Justice and Equity, available at https://www.energy.gov/justice/low-income-communities-bonus-credit-program.

[48] Ibid.

[49] “Low-Income Communities Bonus Credit,” IRS, available at https://www.irs.gov/credits-deductions/low-income-communities-bonus-credit.

[50] “IRS releases Guidance on Low-Income Communities Bonus Credit Program, Inflation Reduction Act,” Forvis Mazars, LLP, August 15, 2023.

[51] Ibid.

[52] 88 Fed. Reg. 55537.

[53] 88 Fed. Reg. 55538.

[54] 88 Fed. Reg. 55538.

Read Part I, Part II, Part III, Part IV, Part V, and Part VI here.

by: Andie Kramer of ASKramer Law

For more news on Energy Tax Credits, visit the NLR Environmental Energy Resources section.

It Ain’t Over ‘til It’s Over: IRS Reminds Taxpayers That Section 280E Applies to Marijuana Companies Until Rescheduling Becomes Law

This is a tax blog. Stay with me – it’s short.

While marijuana advocates celebrate the potential rescheduling of marijuana from Schedule I to Schedule III, the taxman has made clear that marijuana remains a Schedule I substance subject to Section 280E of the Internal Revenue Code. For those who aren’t cannabis tax specialists, 280E provides that:

No deduction or credit shall be allowed for any amount paid or incurred during the taxable year in carrying on any trade or business if such trade or business (or the activities which comprise such trade or business) consists of trafficking in controlled substances (within the meaning of schedule I and II of the Controlled Substances Act) which is prohibited by Federal law or the law of any State in which such trade or business is conducted.

Marijuana is a Schedule I controlled substance and is subject to the limitations of the Internal Revenue Code. As we previously reported, the Justice Department recently published a notice of proposed rulemaking with the Federal Register to initiate a formal rulemaking process to consider rescheduling marijuana to Schedule III under the Controlled Substances Act. That change would remove marijuana from the purview of 280E.

Predictably, a number of cannabis operators couldn’t help themselves and began filing amended returns seeking to avail themselves of what they apparently felt was a change in the law. The response from the IRS is clear:

Taxpayers seeking a refund of taxes paid related to Internal Revenue Code Section 280E by filing amended returns are not entitled to a refund or payment. Until a final rule is published, marijuana remains a Schedule I controlled substance and is subject to the limitations of Internal Revenue Code Section 280E.

The reasoning is simple – marijuana is a Schedule I substance until it is not. While there is currently in place a process that could lead to the rescheduling of marijuana, it has not actually been rescheduled.

Cannabis operators can dream of a time when they will not be subject to the ravages of 280E, but for now that remains just out of grasp, albeit tantalizingly close.

As usual, stay tuned to Budding Trends. We’ll be monitoring all the impacts of rescheduling, including tax implications like this one.

Listen to this post

© 2024 Bradley Arant Boult Cummings LLP
For more on Cannabis, visit the NLR Biotech Food Drug section.

Supreme Court Rules Against Taxpayers in IRC Section 965 Case

On June 20, 2024, the Supreme Court of the United States issued a 7-2 opinion in Moore v. United States, 602 U.S. __ (2024), ruling in favor of the Internal Revenue Service (IRS).

Moore concerned whether US Congress and the IRS could tax US shareholders of controlled foreign corporations (CFCs) on those corporations’ earnings even though the earnings were not distributed to the shareholders. The case specifically focused on the so-called “mandatory repatriation tax” under Internal Revenue Code (IRC) Section 965, a one-time tax on certain undistributed income of a CFC that is payable not by the CFC but by its US shareholders. Some viewed the case as hinging upon whether Congress has the power to tax economic gains that have not been “realized.” (i.e., In the case of a house whose value has appreciated from $500,000 to $600,000, the increased value is “realized” only when the house is sold and the additional $100,000 reaches the taxpayer’s coffers.)

However, Justice Brett Kavanaugh, joined by Chief Justice John Roberts and Justices Sonia Sotomayor, Elena Kagan and Ketanji Brown Jackson, rejected that position on the ground that the mandatory repatriation tax “does tax realized income,” albeit income realized by a CFC. On this basis, they reasoned that the question at issue was whether Congress has the power to attribute realized income of a CFC to (and tax) US shareholders on their respective shares of the undistributed income. This group of justices ultimately decided Congress does have the power.

The majority went out of its way to avoid expressing any opinion as to whether Congress can tax unrealized appreciation, with Justice Amy Coney Barrett’s concurrence and Justice Clarence Thomas’s dissent asserting that it cannot. Perhaps the Court was signaling a distaste for the Billionaire Minimum Income Tax proposed by US President Joe Biden, which would impose a minimum 20% tax on the total income of the wealthiest American households, including both realized and unrealized amounts, among other Democratic proposals.

Practice Point: We previously noted that certain taxpayers should consider filing protective refund claims contingent on the possibility that Moore would be decided in favor of the taxpayers. In light of the case’s outcome, however, those protective claims are now moot.

© 2024 McDermott Will & Emery
For more news on US Shareholders of Foreign Corporations Taxes, visit the NLR Tax section.

Treasury Proposes Clean Electricity Tax Guidance

On May 29, 2024, the Internal Revenue Service (IRS) and the Treasury Department released the pre-publication version of proposed guidance to implement “technology-neutral” clean electricity tax credits, including deeming certain technologies as per se zero-emitting and outlining potential methodologies for determining how other technologies—namely those involving combustion or gasification—could qualify as zero-emitting based on a lifecycle emissions analysis (LCA). The Clean Electricity Production Credit (45Y) and Clean Electricity Investment Credit (48E) were enacted in the Inflation Reduction Act (IRA) of 2022 and replace the current production and investment tax credits that are explicitly tied to certain types of renewable energy technologies.

Stakeholders have cited the 45Y and 48E credits as the most important driver of greenhouse gas (GHG) emission cuts possible from the IRA over the next decade. One study by the Rhodium Group found that the credits could reduce the power sector’s GHG emissions by up to 73 percent by 2035. The tax credits aim to give qualifying facilities the ability to develop technologies over time as they reduce emissions and offer longer-term certainty for investors and developers of clean energy projects. This proposed rule, when finalized, will be a critical driver for developers and companies allocating resources among different projects and investments.

The proposed guidance is scheduled to be published June 3, 2024 in the Federal Register, launching a 60-day comment period. A public hearing will be held August 12-13, 2024.

Proposed Guidance Details

Starting in Fiscal Year (FY) 2025 for projects placed into service after Dec. 31, 2024, 45Y provides taxpayers with a base credit of 0.3 cents (1.5 cents, if the project meets prevailing wage and apprenticeship requirements) per kilowatt of electricity produced and sold or stored at facilities with zero or negative GHG emissions. (These per kilowatt credit values are adjusted for inflation using 1990 as the base year.) Under 48E, taxpayers would receive a 6 percent base credit (30 percent, if the project meets prevailing wage and apprenticeship requirements) on qualified investment in a qualified facility for the year the project is placed in service. Both credits include bonus amounts for projects located in historical energy communities, low-income communities, or on tribal land; for meeting certain domestic manufacturing requirements; or for being part of a low-income residential building or economic benefit project. Direct pay and transferability are options for both credits. Both credits are in effect until 2032, when they become subject to a three-year phaseout.

Technologies recognized as per se zero-emissions in the guidance are wind, solar, hydropower, marine and hydrokinetic, nuclear fission and fusion, geothermal, and certain types of waste energy recovery property (WERP). The guidance also outlines how energy storage can qualify, including by proposing definitions of electricity, thermal, and hydrogen storage property.

A principal debate in the proposal is how to determine, using an LCA, whether certain combustion and gasification (C&G) technologies can qualify as zero-emitting.

The guidance includes a set of definitions and interpretations critical to implementation of the tax credits. For example, the proposed C&G definition includes a hydrogen fuel cell if it “produced electricity using hydrogen that was produced by an electrolyzer powered, in whole or in part, by electricity from the grid because some of the electricity from the grid was produced through combustion or gasification.” The proposed C&G definition would also include both biogas- and biomass-based power, but eligibility depends on the LCA results; for biomass, the guidance seeks comment on what spatial and temporal scales should apply and how land use impacts the LCA.

The guidance states that the IRS intends to establish rules for qualifying facilities that generate electricity from biogas, renewable natural gas, and fugitive sources of methane. The guidance says that Treasury and the IRS “anticipate” requiring that, for such facilities, the gas must originate from the “first productive use of the relevant methane.”

The proposed C&G definition allows for carbon capture and storage (CCS) that meets LCA requirements. However, the IRA does not allow credits to go toward facilities already using certain other credits, including the relatively more generous section 45Q credits for CCS.

Specifically, there are seven other credits that cannot be used in combination with a 45Y or 48E credit: 45 (existing clean electricity production credit); 45J (advanced nuclear electricity credit); 45Q (CCS); 45U (zero-emission nuclear credit); 48 (existing clean electricity investment credit); for 45Y, 48E (new clean electricity production credit); and for 48E, 45Y (new clean electricity investment credit).

The guidance proposes beginning and ending boundaries for LCAs, stating “the starting boundaries would include the processes necessary to produce and collect or extract the raw materials used to produce electricity from combustion or gasification technologies, including those used as energy inputs to electricity production. This includes the emissions effects of relevant land management activities or changes related to or associated with feedstock production.” Another topic in the guidance is the use of carbon offsets to reach net-zero qualification status, with the proposal seeking comment on boundaries: “offsets and offsetting activities that are unrelated to the production of electricity by a C&G Facility, including the production and distribution of any input fuel, may not be taken into account” by an LCA. The guidance also includes rules on qualified interconnection costs in the basis of a low-output associated qualified facility, the expansion of a facility and incremental production, and the retrofitting of an existing facility.

The guidance describes the role of the Department of Energy (DOE) in implementing the tax credits. Any future changes to technologies designated as zero-emitting or to the LCA models must be completed with analyses prepared by DOE’s national labs along with other technical experts. Facilities seeking eligibility may also request a “provisional emissions rate,” which DOE would administer with the national labs and experts “as appropriate.”

Next Steps

As noted above, the proposed guidance is scheduled to be published June 3, 2024 in the Federal Register, launching a 60-day comment period for interested parties to make arguments and provide evidence for changes they would like to see before the rule becomes final. A public hearing will be held August 12-13, 2024. The Treasury Department in consultation with interagency experts plans to carefully review comments and continue to evaluate how other types of clean energy technologies, including C&G technologies, may qualify for the clean electricity credits.

© 2024 Van Ness Feldman LLP
For more news on Clean Energy Tax Credits, visit the NLR Environmental, Energy & Resources section.

The Domestic Content Bonus Credit’s Promising New Safe Harbor

On May 16, 2024, the Internal Revenue Service (IRS) published Notice 2024-41 (Notice), which modifies Notice 2023-38 (Prior Notice) by providing a new elective safe harbor (Safe Harbor) that will allow taxpayers to use assumed domestic cost percentages in lieu of percentages derived from manufacturers’ direct cost information to determine eligibility for the domestic content bonus credit (Domestic Content Bonus). The Notice grants a promising reprieve to the Prior Notice’s relatively inflexible (and arguably impracticable) standard on seeking direct cost information from manufacturers, raising novel structuring considerations for energy producers, developers, investors and buyers.

The Notice also expands the list of technologies covered by the Prior Notice (Applicable Projects).

In this article, we share key takeaways from the Notice as they apply to energy producers, developers and investors and provide a brief overview of the Domestic Content Bonus as well as a high-level summary of the Notice’s substantive content.

IN DEPTH

KEY TAKEAWAYS FROM THE NOTICE

The Notice provides a key step forward in eliminating qualification challenges for the Domestic Content Bonus by providing an alternative to the Prior Notice’s stringent requirement of seeking direct cost information from manufacturers. In short, a taxpayer can aggregate the assumed percentages in the Notice that correspond with the US-made manufactured products in its project. If the assumed percentages total is greater than the manufactured product percentage applicable to such project (currently 40%), then the taxpayer is treated as satisfying the manufactured product requirement. Although the Notice promises forthcoming proposed regulations that could amend or override the Notice, this gives taxpayers time to appropriately interpret the latest rules and respond accordingly.

The new guidance’s impact will likely require restructuring to the existing development of energy projects as it relates to the Domestic Content Bonus. Below, we outline some key considerations for energy producers, developers, investors and buyers alike:

  • The Safe Harbor is expected to dramatically increase the availability of the Domestic Content Bonus. The Prior Notice’s challenging cost substantiation requirements left most industry participants on the sidelines. Initial feedback from developers, investors and credit buyers was extremely positive, and we have already seen fulsome renegotiation and speedy agreement between counterparties over domestic content contractual provisions in project documents.
  • While the Safe Harbor eliminates the requirement to seek direct cost information from manufacturers for certain Applicable Projects, a taxpayer’s obligations with respect to substantiation requirements for manufacturers’ US activities is not clear in the Notice. Given the standing federal income tax principles on recordkeeping and substantiation, taxpayers should carefully reconsider positions on diligence and review existing relationships with manufacturers.
  • Although the Notice expressly provides that the Safe Harbor is elective with respect to a specific Applicable Project, it’s unclear whether the Safe Harbor is extended by default to any and all of a taxpayer’s Applicable Projects upon election effect or whether an elective position is required with respect to each Applicable Project. Taxpayers, especially those with multiple Applicable Projects, should consider the various implications resulting from an elective position prior to reliance on the Safe Harbor.
  • For Safe Harbor purposes, the Notice provides a formula for computing a single domestic cost percentage for solar energy property and battery energy storage technologies that are treated as a single energy project (PV+BESS Project), but ambiguity exists as to whether such technologies should be aggregated for other purposes under the investment tax credit.
  • It’s unclear how the calculations would operate for repowered facilities given the assumed domestic cost percentage approach.
  • The Notice limits the Safe Harbor to solar photovoltaic, onshore wind and battery energy storage systems, leaving taxpayers with other types of Applicable Projects stranded with the Prior Notice. For example, the Notice does not cover renewable natural gas or fuel cell. The IRS seeks comments on whether the Safe Harbor should account for other technologies, the criteria and how often the list of technologies should be updated. Affected taxpayers should fully consider the requested comments and provide feedback as necessary.
  • The IRS seeks comments on various issues with respect to taxpayers who have a mix of foreign and domestic manufactured product components (mixed source items). Taxpayers with mixed source items that the Notice attributes as disregarded and entirely foreign sourced (notwithstanding the domestic portion) should take cautionary note and provide feedback as necessary.

BACKGROUND: THE DOMESTIC CONTENT BONUS CREDIT

The Inflation Reduction Act of 2022 spurred the creation of “adder” or “bonus” incentive tax credits. In pertinent part, Applicable Projects could further qualify for an increased credit (i.e., the Domestic Content Bonus) upon satisfaction of the domestic content requirement.

To qualify for the Domestic Content Bonus, taxpayers must meet two requirements. First, steel or iron components of the Applicable Project that are “structural” in nature must be 100% US manufactured (Steel or Iron Requirement). Second, costs associated with “manufactured components” of the Applicable Project must meet the “adjusted percentage” set forth in the Internal Revenue Code (Manufactured Products Requirement). For projects beginning construction before 2025, the adjusted percentage is 40%.

The Prior Notice provided guidance for meeting these requirements. Taxpayers should begin by identifying each “Applicable Project Component” (i.e., any article, material or supply, whether manufactured or unmanufactured, that is directly incorporated into an Applicable Project). Subsequently, taxpayers must determine whether the Applicable Project Component is subject to the Steel or Iron Requirement or the Manufactured Products Requirement.

If the Applicable Project Component is steel or iron, it must be 100% US manufactured with no exception. If the Applicable Project Component is a manufactured product, such component and its “manufactured product components” must be tested as to whether they are US manufactured. If the manufactured product and all its manufactured product components are US manufactured, then the manufacturer’s cost of the manufactured product is included for purposes of satisfying the adjusted percentage. If any of the manufactured product or its manufactured product components are not US manufactured, only the cost to the manufacturer of any US manufactured product components are included.

The core tension lies in sourcing the total costs from the manufacturer of the manufactured product or its manufactured product components. There’s a substantiation requirement on the taxpayer imposed by the Prior Notice, but there’s also a shrine of secrecy from the corresponding manufacturer.

Apparently acknowledging the need for reconciliation, the Notice aims to pave a promising path for covered technologies (i.e., solar, onshore wind and battery storage).

THE MODIFICATIONS: A PROMISING PATH FOR THE DOMESTIC CONTENT BONUS CREDIT

NEW ELECTIVE SAFE HARBOR

Generally

The Safe Harbor allows a taxpayer to elect to assume the domestic percentage costs (assumed cost percentages) for manufactured products. Importantly, the election eliminates the requirement for a taxpayer to source a manufacturer’s direct costs with respect to the taxpayer’s Applicable Project and instead allows for the reliance on the assumed cost percentages. The Notice prohibits any partial Safe Harbor reliance, meaning taxpayers who elect to use the Safe Harbor must apply it in its entirety to the Applicable Project for which the taxpayer makes such election.

The Safe Harbor only applies to the Applicable Projects of solar photovoltaic facilities (solar PV), onshore wind facilities and battery energy storage systems (BESS). Taxpayers with other technologies must continue to comply with the Prior Notice. Notably, the Notice expands Solar PV into four subcategories: Ground-Mount (Tracking), Ground-Mount (Fixed), Rooftop (MLPE) and Rooftop (String), each having differing assumed cost percentages for the respective manufactured product component. Similarly, BESS is expanded into Grid-Scale BESS and Distributed BESS, each with differing assumed cost percentages for the respective manufactured product component.

For solar PV, onshore wind facilities and BESS, the Safe Harbor provides a list via Table 1[1] (Safe Harbor list) that denotes each relevant manufactured product component with its corresponding assumed cost percentage. Each manufactured product component (and steel or iron component) are classified under a relevant Applicable Project Component.

Of note are the disproportionately higher assumed cost percentages of certain listed components within the Safe Harbor list. For solar PV, cells under the PV module carry an assumed cost percentage of 36.9% (Ground-Mount (Tracking)), 49.2% (Ground-Mount (Fixed)), 21.5% (Rooftop (MLPE)) or 30.8% (Rooftop (String)).

For onshore wind facilities, blades and nacelles under wind turbine carry an assumed cost percentage of 31.2% and 47.5%, respectively.

For BESS, under battery pack, Grid-scale BESS cells and Distributed BESS packaging carry an assumed cost percentage of 38.0% and 30.15%, respectively. Accordingly, projects incorporating US manufactured equipment in these categories are likely to meet the Manufactured Products Requirement with little additional spend. Conversely, projects without these components are unlikely to satisfy the threshold.

Mechanics of the Safe Harbor

Reliance on the Safe Harbor is a simple exercise of component selection and subsequent assumed cost percentage addition. Put more specifically, a taxpayer identifies the Applicable Project on the Safe Harbor list and assumes the list of components within (without regard to any components in the taxpayer’s project that are not listed). Then, the taxpayer (i) identifies which of the components within the Safe Harbor list are in their project, (ii) confirms that any steel or iron components on the Safe Harbor list fulfill the Steel or Iron Requirement, and (iii) sums the assumed cost percentages of all identified listed components that are 100% US manufactured to determine whether their Applicable Project meets the relevant adjusted percentage threshold.

The Notice addresses nuances in situations involving mixed 100% US manufactured and 100% foreign manufactured components that are of like-kind, component production costs and treatment for PV+BESS Projects.

The Notice also provides that a taxpayer adjusts for a mix of US manufactured and foreign manufactured components by applying a weighted formula to account for the foreign components.

Consistent with the Prior Notice, the Notice provides that the assumed cost percentage of “production” costs may be summed and included in the domestic cost percentage only if all the manufactured product components of a manufactured product are 100% US manufactured.

Lastly, in accordance with the view that a PV+BESS Project is treated as a single project, the Notice provides that a taxpayer may use a weighted formula to determine a single domestic content percentage for the project.

The numerator is the sum of the (i) aggregated assumed cost percentages of the manufactured product components that constitute the solar PV multiplied by the solar PV nameplate capacity and (ii) aggregated assumed cost percentages of the manufactured product components that constitute BESS multiplied by the BESS nameplate capacity and the “BESS multiplier.” The BESS multiplier converts the BESS nameplate capacity into proportional equivalency (i.e., equivalent units) to the solar PV nameplate capacity. The denominator is the sum of the solar PV nameplate capacity and the BESS nameplate capacity. Divided accordingly, the final fraction constitutes the single domestic content percentage that the taxpayer uses to determine whether its PV+BESS Project meets the relevant manufactured product adjusted percentage threshold.

Additionally, the Notice confirms that taxpayers can ignore any components not included in the Safe Harbor list. Compared with the Prior Notice, this can be a benefit for taxpayers with non-US manufactured products that are not on the Safe Harbor list. Conversely, for taxpayers with US manufactured products that are not on the Safe Harbor list, they lose the benefit of including such costs in the Manufactured Products Requirement. However, this is mostly a benefit because it eliminates any ambiguity surrounding the treatment of components not listed in the Prior Notice.

EXPANSION OF COVERED TECHNOLOGIES

The Notice adds “hydropower facility or pumped hydropower storage facility” to the list of Applicable Projects as a modification to Table 2 in the Prior Notice. The modification is complete with a list of a hydropower facility or pumped hydropower storage facility’s Applicable Project Components that are delineated as either steel or iron components or manufactured products, though no assumed cost percentages are provided. Further, the Prior Notice’s “utility-scale photovoltaic system” is redesignated as “ground-mount and rooftop photovoltaic system.”

CERTIFICATION

To elect to rely on the Safe Harbor, in its domestic content certification statement, a taxpayer must provide a statement that says they are relying on the Safe Harbor. This is submitted with the taxpayer’s tax return.

RELIANCE AND COMMENT PERIOD

Taxpayers may rely on the rules set forth in the Notice and the Prior Notice (as modified by the Notice) for Applicable Projects, the construction of which begins within 90 days after the publication of intended forthcoming proposed regulations.

Comments should be received by July 15, 2024.

CONCLUSION

While this article provides a high-level summary of the substantive content in the Notice, the many potential implications resulting from these developments merit additional attention. We will continue to follow the development of the guidance and provide relevant updates as necessary.

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