Solar ITC for Commercial Real Estate: Section 48E Credits, Bonus Adders, and MACRS Interaction

Key Takeaways

What Is the Solar ITC

The solar investment tax credit is a federal incentive that reduces the income tax liability of a taxpayer who installs qualified solar energy property on a commercial building. Unlike a deduction (which reduces taxable income), the ITC is a credit (which reduces tax owed dollar for dollar). A $300,000 ITC on a $1,000,000 solar installation eliminates $300,000 of federal tax liability in the year the system is placed in service.

For commercial real estate, the solar ITC applies to photovoltaic (PV) systems installed on rooftops, parking structures, ground-mounted arrays on owned parcels, and building-integrated photovoltaics (BIPV). The credit is claimed by the owner of the solar property, which is typically the building owner or a special-purpose entity structured for tax credit monetization. The Department of Energy provides an overview of eligible technologies for commercial installations.

The ITC has existed in various forms since the Energy Policy Act of 2005, but the Inflation Reduction Act of 2022 (IRA) restructured it significantly. The IRA replaced the flat 30% credit with a tiered structure that rewards compliance with labor standards (prevailing wage and apprenticeship requirements) and offers bonus adders for projects that meet additional policy objectives. The subsequent One Big Beautiful Bill Act (OBBBA, signed July 2025) imposed new construction commencement and placed-in-service deadlines that have compressed the timeline for developers considering solar installations.

From a real estate underwriting perspective, the solar ITC is a capital stack tool. It reduces the effective cost of a solar installation by 30% to 70% (depending on bonus adder eligibility), which changes the return profile of a property acquisition, development, or capital improvement. The credit, combined with accelerated depreciation under MACRS, can make solar installations accretive to property-level returns even in markets where electricity savings alone would not justify the capital expenditure.

Section 48 vs Section 48E

The IRA created two parallel investment tax credit provisions. Understanding which applies to a given project is the first step in any solar ITC analysis.

Section 48: The Legacy Credit

IRC Section 48 is the original investment tax credit for energy property, in effect for decades. Under the IRA, Section 48 continues to apply to solar property for which construction begins before January 1, 2025. The credit rate under Section 48 is 30% (or 6% without PWA compliance) for solar energy property, with the same bonus adder structure as Section 48E.

Most commercial solar projects beginning construction in 2025 or later fall under Section 48E rather than Section 48. However, projects that commenced construction before January 1, 2025 (and can document that fact through the IRS safe harbors) remain eligible for the Section 48 credit even if they are not placed in service until later.

Section 48E: The Clean Electricity Investment Credit

IRC Section 48E, added by the IRA, is the technology-neutral clean electricity investment credit. It applies to any qualified facility that generates electricity with a greenhouse gas emissions rate of zero. Solar PV qualifies automatically. Section 48E applies to facilities for which construction begins after December 31, 2024.

The mechanics are nearly identical to Section 48 for solar projects: same base credit rates (6% or 30%), same bonus adders, same PWA requirements. The key difference is that Section 48E is technology-neutral (it covers wind, geothermal, nuclear, and other zero-emission technologies alongside solar) and was designed to be the permanent successor to the technology-specific Section 48 credit.

For CRE developers evaluating rooftop solar in 2026, Section 48E is the operative statute. The OBBBA modified Section 48E by imposing a construction commencement deadline of July 4, 2026, and a placed-in-service deadline of December 31, 2027. These deadlines are discussed in detail in the OBBBA Timeline Changes section below.

Base Credit and PWA Requirements

The IRA established a two-tier credit structure. The base credit is 6% of the cost of qualified solar energy property. If the project satisfies prevailing wage and apprenticeship (PWA) requirements, the credit increases fivefold to 30%. This is not a bonus; it is the mechanism Congress chose to link the full credit to labor standards.

The 6% Base Credit

Projects that do not meet PWA requirements receive a 6% investment tax credit. For a $1,000,000 solar installation, the credit would be $60,000. At this level, the ITC alone rarely justifies a commercial solar installation; the 6% rate was intentionally designed to be insufficient, pushing developers toward PWA compliance.

There is one exception: projects under 1 MW of nameplate capacity are exempt from PWA requirements and still receive the full 30% credit. This is significant for CRE developers because many rooftop installations on individual buildings fall below the 1 MW threshold. A typical 50,000 square foot commercial building supports approximately 200 to 400 kW of rooftop solar, well within the exemption.

The 30% Enhanced Credit with PWA Compliance

To qualify for the full 30% credit on projects of 1 MW or greater, the developer must satisfy two labor requirements during both construction and for a specified period after the facility is placed in service.

Prevailing Wage Requirement

All laborers and mechanics employed in the construction, alteration, or repair of the solar facility must be paid wages at rates not less than the prevailing rates determined by the Secretary of Labor under the Davis-Bacon Act. The prevailing wage rates are published by the Department of Labor's Wage and Hour Division and vary by county, trade, and type of construction.

The prevailing wage requirement applies during construction and for 5 years after the facility is placed in service (covering maintenance and repair work). This means that if you hire electricians to perform maintenance on the solar array in year 3 of operation, those electricians must be paid prevailing wages. The requirement runs with the project, not just the construction phase.

Compliance steps for prevailing wage:

• Determine the correct wage determination for the project's county and type of construction (building, heavy, highway, or residential) using the SAM.gov wage determination database.
• Include the applicable wage determination in all construction contracts and subcontracts.
• Require weekly certified payroll reports from all contractors and subcontractors.
• Maintain payroll records for at least 6 years after the placed-in-service date.
• Ensure prevailing wages apply to maintenance and repair contractors for 5 years post-placement.

Apprenticeship Requirement

For projects beginning construction in 2024 or later, a minimum percentage of total labor hours must be performed by qualified apprentices registered in programs approved by the Department of Labor or a state apprenticeship agency. The required percentage is:

• Construction beginning in 2023: 12.5% of total labor hours
• Construction beginning in 2024 or later: 15% of total labor hours

The apprenticeship requirement applies to each contractor and subcontractor individually, not to the project as a whole. A contractor who employs four or more workers on the project must ensure that at least 15% of total labor hours are performed by qualified apprentices.

There is a good-faith exception: if a contractor requests qualified apprentices from a registered apprenticeship program and the request is denied or not responded to within 5 business days, the contractor is deemed to have satisfied the apprenticeship requirement. This exception has been critical for solar installations in areas with limited apprenticeship program availability.

Cure Provision for PWA Violations

The IRA includes a cure provision for PWA non-compliance. If a violation is discovered, the taxpayer can retain the full 30% credit by paying each affected worker the difference between the wages paid and the prevailing wage, plus interest, within 180 days of the determination, and by paying a penalty to the IRS equal to $5,000 per affected worker (or $10,000 per worker for intentional violations). This cure mechanism reduces the binary risk of losing the entire 24-percentage-point enhancement due to a single payroll error.

Bonus Adders: Stacking to 70%

Beyond the base 30% credit (with PWA compliance), Section 48E provides four bonus adder categories that can increase the effective credit rate. Each adder is independent; a project that qualifies for multiple adders receives all of them.

Domestic Content Bonus (+10%)

The domestic content bonus adder increases the ITC by 10 percentage points (from 30% to 40%) for projects where the steel, iron, and manufactured components meet domestic sourcing thresholds. TheTreasury Department proposed regulations (Notice 2023-38, later formalized) define the requirements:

• Steel and iron: All structural steel and iron components must be produced in the United States. "Produced" means all manufacturing processes, from initial melting through application of coatings, occur domestically.
• Manufactured components: A minimum percentage of the total cost of manufactured components must be attributable to components mined, produced, or manufactured in the United States. The threshold is 40% for facilities beginning construction in 2025 and 2026, increasing to 45% in 2027 and 55% in 2028 and beyond.

For solar PV, the manufactured components include modules, inverters, racking systems, wiring, and trackers (for ground-mount systems). The domestic content requirement has been challenging for solar because most PV modules are manufactured outside the United States, although domestic module manufacturing capacity has expanded significantly since the IRA's passage. Developers pursuing this adder should confirm supply chain sourcing with their EPC contractor before committing to a domestic content certification in their tax credit documentation.

Energy Community Bonus (+10%)

The energy community bonus adder provides an additional 10 percentage points for solar facilities located in designated energy communities. The IRS has defined three categories of qualifying locations:

• Brownfield sites: Properties previously used for industrial or commercial purposes where redevelopment is complicated by real or perceived contamination. Many industrial properties with rooftop solar potential qualify.
• Metropolitan or non-metropolitan statistical areas with significant fossil fuel employment: Areas where 0.17% or more of direct employment (or 25% or more of local tax revenue) is related to fossil fuel extraction, processing, transport, or storage, and the area has an unemployment rate at or above the national average.
• Coal closure communities: Census tracts (or adjacent tracts) containing a coal mine that closed after 1999 or a coal-fired electric generating unit that retired after 2009.

The IRS publishes annual lists of qualifying energy community census tracts and statistical areas. CRE developers should check their property's census tract against the current list before beginning solar installation planning. The energy community bonus is particularly relevant for industrial properties in former manufacturing or energy-producing regions, which often have large, unobstructed rooftops ideal for solar installations.

Low-Income Community Bonus (+10% or +20%)

The low-income community bonus has two tiers and is allocated through a separate application process administered by the Department of Energy:

• Category 1 (+10%): Facilities located in low-income communities (census tracts with poverty rates of 20% or higher, or median family income below 80% of the area median) or on Indian land.
• Category 2 (+10%): Facilities that are part of a qualified low-income residential building project (such as a federally subsidized affordable housing development).
• Category 3 (+20%): Facilities that are part of a qualified low-income economic benefit project, where at least 50% of the financial benefits of the electricity produced flow to households with income below 200% of the federal poverty line.
• Category 4 (+20%): Facilities that are part of a qualified low-income residential building project located on Indian land.

The low-income bonus is capacity-limited. The DOE allocates 1.8 GW of capacity annually across the four categories. This means the bonus is not available on demand; developers must apply during an allocation round and compete for limited capacity. For CRE developers with multifamily properties in qualifying census tracts, Category 2 is particularly attractive because it pairs naturally with affordable housing portfolios.

How Adders Stack in Practice

Consider a 600 kW rooftop solar installation on a multifamily affordable housing building located in a qualifying energy community census tract, using domestically manufactured modules:

Table 1. Bonus adder stacking example. A qualifying multifamily project in an energy community with domestic content achieves a 60% effective ITC rate. If Category 3 or 4 applies instead of Category 2, the effective rate reaches 70%.

In practice, achieving 50% or higher requires careful planning. The domestic content requirement restricts module and inverter sourcing. The energy community qualification depends on the property's geographic location, which is fixed. And the low-income bonus requires a competitive allocation from the DOE. Most commercial solar projects achieve the base 30% credit with PWA compliance; the adders are incremental value that informed developers pursue when the property and project characteristics align.

MACRS Depreciation and Basis Reduction

The ITC is not the only federal tax benefit available for commercial solar installations. Solar energy property is classified as 5-year MACRS property under the Modified Accelerated Cost Recovery System, meaning the cost of the installation can be depreciated over 5 years (using a half-year convention) rather than the 27.5- or 39-year depreciation schedule that applies to the building itself. This accelerated depreciation creates significant additional tax benefits in the early years of ownership.

The Half-Credit Rule (Basis Reduction)

When a taxpayer claims the ITC on solar property, the depreciable basis of that property must be reduced. However, the reduction is not equal to the full credit amount. Under the "half-credit rule" (IRC Section 50(c)), the depreciable basis is reduced by 50% of the ITC amount, not 100%.

Here is how this works for a $1,000,000 solar installation with a 30% ITC:

• ITC amount: $1,000,000 x 30% = $300,000
• Basis reduction: $300,000 x 50% = $150,000
• Depreciable basis: $1,000,000 - $150,000 = $850,000

The taxpayer claims a $300,000 ITC and depreciates $850,000 over 5 years. Without the half-credit rule (if the full ITC amount reduced basis), the depreciable basis would be only $700,000. The half-credit rule preserves an additional $150,000 of depreciable basis, which translates to roughly $55,500 in additional tax savings at a 37% marginal rate.

Bonus Depreciation in 2026

Under the Tax Cuts and Jobs Act of 2017 (as modified by subsequent legislation), bonus depreciation allows taxpayers to deduct a percentage of the cost of qualifying assets in the first year. The bonus depreciation rate has been phasing down:

• 2022: 100% bonus depreciation
• 2023: 80% bonus depreciation
• 2024: 60% bonus depreciation
• 2025: 40% bonus depreciation
• 2026: 20% bonus depreciation
• 2027 and beyond: 0% bonus depreciation (unless extended by Congress)

For solar property placed in service in 2026, 20% bonus depreciation applies to the adjusted depreciable basis (after the ITC basis reduction). Using the example above: the $850,000 depreciable basis generates a $170,000 first-year bonus depreciation deduction, with the remaining $680,000 depreciated over the standard 5-year MACRS schedule.

Combined Tax Benefit: ITC + MACRS

The combined effect of the ITC and MACRS depreciation is substantial. For a $1,000,000 solar installation placed in service in 2026, assuming a 30% ITC, 20% bonus depreciation, and a 37% marginal tax rate:

Table 2. Combined ITC and MACRS tax benefits for a $1M solar installation in 2026. Total federal tax savings over the depreciation period exceed $614,000, representing more than 61% of the installation cost.

Total federal tax savings: $300,000 (ITC) + $314,500 (depreciation at 37%) = $614,500, or approximately 61.5% of the installation cost. This calculation does not include state-level tax benefits, which vary by jurisdiction but can add an additional 3% to 10% in present-value tax savings.

Direct Pay and Transferability

The IRA introduced two mechanisms that expanded access to the ITC beyond taxpayers with sufficient tax liability to use the credit directly. Both are significant for specific segments of the CRE market.

Direct Pay (Elective Pay) for Tax-Exempt Entities

Under IRC Section 6417, certain tax-exempt entities can elect to receive the ITC as a direct payment from the IRS rather than as a credit against tax liability. Eligible entities include:

• Tax-exempt organizations under IRC Section 501(a)
• State and local governments (and political subdivisions)
• Indian tribal governments
• The Tennessee Valley Authority
• Alaska Native Corporations
• Rural electric cooperatives

Direct pay is particularly relevant for two CRE contexts. First, municipal governments that own public buildings (courthouses, libraries, community centers) can install solar and receive a direct cash payment equal to 30% (or more, with adders) of the installation cost. Second, nonprofit affordable housing developers that own multifamily properties can monetize the ITC without needing a taxable investor, simplifying the deal structure considerably.

REITs do not qualify for direct pay because they are taxable entities (even though they typically have minimal federal tax liability due to the dividend deduction). REITs must use the transferability mechanism or a partnership structure to monetize the ITC.

ITC Transferability

Under IRC Section 6418, introduced by the IRA, any taxpayer eligible for the ITC can elect to transfer all or a portion of the credit to an unrelated third-party buyer in exchange for cash. This "transferability" mechanism replaced the need for complex tax equity partnership structures (such as inverted leases or partnership flips) that were previously required to monetize clean energy credits.

Key mechanics of ITC transferability:

• The buyer must be unrelated to the seller (not a related party under IRC Section 267 or 707(b)).
• The transfer is for cash only. No property, services, or other consideration can be part of the transaction.
• The cash received is not taxable income to the seller, and the cash paid is not deductible by the buyer.
• The buyer takes the credit as if they had generated it and applies it against their own tax liability.
• Recapture risk transfers with the credit. If a recapture event occurs, the buyer (not the seller) is responsible for repaying the recaptured credit to the IRS, unless the transfer agreement specifies otherwise.

Credit transfer pricing in the current market ranges from approximately $0.90 to $0.95 per dollar of credit, according to marketplace data from Crux Climate. A developer with a $300,000 ITC who transfers the credit at $0.92 per dollar receives $276,000 in cash. The $24,000 "discount" is the buyer's return for providing capital and bearing recapture risk.

For CRE developers, transferability has simplified solar ITC monetization dramatically. Before the IRA, a developer without sufficient tax liability would need to structure a partnership flip or sale-leaseback with a tax equity investor, incurring legal costs of $50,000 to $150,000 and adding months to the transaction timeline. With transferability, the developer can simply sell the credit on a marketplace platform and receive cash.

OBBBA Timeline Changes

The One Big Beautiful Bill Act (OBBBA), signed in July 2025, imposed significant new deadlines on the Section 48E clean electricity investment credit. These deadlines have compressed the window for CRE developers considering solar installations.

Construction Commencement Deadline: July 4, 2026

Under the OBBBA, a Section 48E facility must begin construction by July 4, 2026, to qualify for the credit. "Beginning of construction" is determined under the IRS safe harbor framework established in Notice 2013-29 and subsequent guidance. Two alternative tests satisfy the requirement:

• Physical Work Test: The taxpayer begins physical work of a significant nature at the project site or at a factory where components are manufactured. For rooftop solar, this typically means beginning installation of racking systems, conduit, or inverter pads. Preliminary activities (surveying, permitting, engineering) do not qualify.
• Five Percent Safe Harbor: The taxpayer pays or incurs at least 5% of the total cost of the facility. For a $1,000,000 installation, a binding contract for $50,000 or more in equipment or services satisfies this test. This is the more commonly used test because it can be satisfied with equipment purchase orders.

Once construction has commenced, the taxpayer must make continuous progress toward completion. Under the current IRS "Continuity Safe Harbor," the facility must be placed in service within 4 calendar years after the year construction begins (though this has historically been extended through subsequent IRS notices).

Placed-in-Service Deadline: December 31, 2027

The OBBBA also requires that Section 48E property be placed in service by December 31, 2027. "Placed in service" means the solar system is installed, connected to the grid (or to the building's electrical system), and available for its intended use. For rooftop solar, this means the system is mechanically complete, has passed final electrical inspection, and has received permission to operate (PTO) from the local utility.

The placed-in-service deadline creates a hard stop. Even if construction commenced before July 4, 2026, the facility must be operational by the end of 2027 to claim the Section 48E credit. This is a departure from the previous framework, where construction commencement alone (with continuity) was sufficient to lock in credit eligibility regardless of when the facility was ultimately placed in service.

What Happens After the Deadlines

The OBBBA did not eliminate clean energy tax credits entirely. Rather, it imposed a sunset on the Section 48E clean electricity investment credit as enacted by the IRA. Solar projects that do not meet the construction commencement or placed-in-service deadlines would not qualify for Section 48E. Whether any successor credit will be enacted is a matter of future legislation. The Section 48 credit (the legacy provision) also has its own phase-down schedule, which varies by the date construction begins.

For underwriting purposes, the conservative assumption is that the ITC will not be available for solar installations placed in service after December 31, 2027, unless Congress enacts new legislation. This assumption should be clearly stated in any pro forma that includes solar ITC benefits.

Worked Example: 500 kW Rooftop Solar

To illustrate how the ITC affects real estate underwriting, consider a concrete scenario: a CRE developer acquiring a 120-unit multifamily apartment building with a flat roof suitable for a 500 kW rooftop solar installation. The property is located in a qualifying energy community census tract. The developer plans to use domestically manufactured modules.

Solar Installation Assumptions

Table 3. Solar installation assumptions for the worked example. The 500 kW system is below the 1 MW PWA exemption threshold.

ITC Calculation

Table 4. ITC calculation showing a 50% effective credit rate through stacking the base credit with domestic content and energy community bonus adders.

MACRS Depreciation Calculation

Table 5. MACRS depreciation with the half-credit rule applied. The 50% ITC reduces the depreciable basis by $250,000 (half of the $500,000 credit), preserving $750,000 of depreciable basis.

Impact on Acquisition Underwriting

Now consider how the solar installation changes the acquisition underwriting for the property. The developer is acquiring the 120-unit multifamily building for $15,000,000 and plans to install the 500 kW rooftop solar system as a capital improvement.

Table 6. Acquisition underwriting comparison. Solar + ITC adds $78,000 in annual electricity savings, generates $722,400 in present-value tax benefits (at 8% discount rate), and improves the effective cap rate by 31 basis points.

The solar installation adds $1,000,000 to total capital deployed, but the $500,000 ITC offsets half the cost immediately. The remaining $500,000 generates $277,500 in depreciation tax benefits over 5 years and $78,000 per year in electricity savings for 25 years. On a net present value basis (at an 8% discount rate), the solar installation with ITC increases property value by approximately $722,400 while requiring only $500,000 in net capital, producing a return on incremental capital well in excess of the property's unlevered return.

Underwriting Considerations for CRE

The solar ITC interacts with several aspects of commercial real estate underwriting that deserve specific attention.

Property Type Suitability

Not every commercial property is suitable for rooftop solar. The key physical considerations:

• Roof condition and remaining life: Solar panels have a 25-year useful life. Installing them on a roof with only 5 to 10 years of remaining life creates a costly problem. The roof should have at least 15 to 20 years of remaining useful life, or the developer should plan to reroof before installation.
• Structural capacity: Solar panels and racking add approximately 3 to 5 pounds per square foot of dead load. Older buildings may require structural reinforcement, which adds to the installation cost and can reduce the net ITC benefit.
• Shading and orientation: Rooftops with significant shading from taller adjacent buildings, mechanical equipment, or trees will produce less electricity, reducing the economic benefit. South-facing exposure (in the Northern Hemisphere) is ideal.
• Electrical infrastructure: The building's electrical panel and service must accommodate the solar interconnection. Panel upgrades or service upgrades can add $20,000 to $75,000 to the project cost.

The property types most commonly suited for commercial solar are industrial warehouses (large, flat, unobstructed roofs), retail strip centers (long, low-rise structures), multifamily apartment buildings (flat or low-slope roofs), and office buildings with minimal rooftop mechanical equipment.

Ownership Structure and Credit Allocation

The ITC is claimed by the owner of the solar property for tax purposes. In a standard building ownership structure, the building owner installs the solar system and claims the ITC on their own tax return. However, several alternative structures exist:

• Direct ownership: The building owner or operating entity installs and owns the solar system. Simplest structure. The ITC offsets the owner's tax liability (or can be transferred under Section 6418).
• Power Purchase Agreement (PPA): A third-party solar developer installs, owns, and maintains the system. The building owner purchases electricity at a contractual rate (typically below retail). The solar developer claims the ITC. The building owner receives no tax benefit but also bears no installation cost or maintenance risk.
• Solar lease: Similar to a PPA, but the building owner pays a fixed monthly lease payment rather than a per-kWh rate. The lessor claims the ITC.
• Partnership flip: The building owner and a tax equity investor form a partnership. The tax equity investor receives the ITC and depreciation benefits. After a specified period (typically the 5-year recapture period), the building owner buys out the investor's interest. This structure is common for larger installations but involves significant legal costs.

For CRE owners with sufficient tax liability, direct ownership with credit transfer (selling the credit under Section 6418) is typically the most efficient structure. For REITs and tax-exempt entities, PPAs or the direct pay election (for qualifying entities) are the primary paths to solar economics.

Impact on Property Valuation

Solar installations can affect property valuation through several channels. The most direct is the increase in NOI from reduced electricity costs. If a solar system reduces electricity expenses by $78,000 per year on a property valued at a 6% cap rate, the capitalized value of the electricity savings is $1,300,000, significantly exceeding the $1,000,000 installation cost (before accounting for the ITC).

However, appraisers vary in how they treat solar-related income and expenses. Some capitalize the full electricity savings into NOI. Others treat solar as personal property (rather than real property) and exclude it from the real estate valuation. The treatment can affect loan-to-value ratios, debt sizing, and refinancing proceeds. Developers should discuss the intended solar installation with their lender and appraiser before committing to the project to ensure the anticipated value enhancement will be recognized in the financing.

Insurance and Maintenance

Solar installations increase property insurance premiums, typically by $1,000 to $5,000 per year for a commercial system. The additional coverage protects against equipment damage, fire risk (rare but consequential), and liability. Ongoing maintenance costs are modest: $10 to $20 per kW per year for monitoring, cleaning, and inverter maintenance. For a 500 kW system, annual maintenance runs approximately $5,000 to $10,000.

These costs should be included in the underwriting as operating expenses. They reduce the net benefit of the solar installation but do not typically eliminate the economic case, especially when the ITC and MACRS benefits are included in the analysis.

Common Mistakes

These are the errors that most frequently appear in solar ITC underwriting for commercial real estate projects:

• Applying the full ITC to reduce depreciable basis. The half-credit rule means the depreciable basis is reduced by 50% of the ITC amount, not 100%. A developer who reduces basis by the full credit amount will understate depreciation deductions and overstate the effective tax rate on the investment.
• Assuming PWA compliance is automatic. For systems of 1 MW or greater, PWA compliance is a deliberate process that requires specific contract language, certified payroll documentation, and ongoing monitoring for 5 years after placed-in-service. Failure to comply drops the credit from 30% to 6%, a loss of 80% of the credit value.
• Ignoring the OBBBA construction commencement deadline. For Section 48E projects, construction must commence by July 4, 2026. The 5% safe harbor requires a binding contract for at least 5% of total facility cost. Developers who assume they can begin the procurement process in late 2026 and still qualify for the credit may find themselves outside the eligibility window.
• Conflating the ITC with an operating income item. The ITC is a one-time tax credit, not annual income. It reduces tax liability in the placed-in-service year (or the year of the election, for transferred credits). Do not capitalize the ITC into NOI or include it in a cap rate calculation. It belongs in the capital stack analysis, not the operating pro forma.
• Ignoring recapture risk in disposition analysis. If the property is sold within 5 years of the solar placed-in-service date, a portion of the ITC must be repaid. A developer who underwrites a 3-year hold without accounting for ITC recapture will overstate disposition proceeds and understate the tax obligation.
• Overstating bonus adder eligibility. Each bonus adder has specific qualification criteria. The domestic content bonus requires certified supply chain documentation. The energy community bonus requires the property to be in a specific census tract on the IRS published list. The low-income bonus requires a DOE allocation. Assuming all three adders without confirming qualification overstates the credit by 20 to 30 percentage points.
• Using the wrong depreciation schedule. Solar energy property is 5-year MACRS property, not 39-year property (commercial buildings) or 27.5-year property (residential rental). Using the building depreciation schedule instead of the solar-specific schedule understates the present value of depreciation deductions by approximately 60%.
• Failing to separate land and solar basis. The ITC applies to the cost of the solar energy property only, not the land or the building. In a development project, the solar installation cost must be clearly identified and segregated in the sources and uses to ensure the ITC is calculated on the correct basis.

Related Articles

This article is part of the tax credits underwriting series. Each article covers a different federal credit program relevant to commercial real estate:

• Historic Tax Credits and Qualified Rehabilitation Expenditures. The 20% federal HTC for certified historic structures, QRE calculation, and partnership structuring.
• New Markets Tax Credits (NMTC) and the Leveraged Structure. NMTC allocation mechanics, the leveraged lending structure, and QLICI requirements.
• 45L Energy Credits for Multifamily New Construction. The Section 45L tax credit for energy-efficient residential buildings and multifamily developments.
• Layering Multiple Credits: LIHTC, HTC, and NMTC. How to combine federal tax credit programs on a single project without double-dipping.
• LIHTC 101: How the Program Works. The foundational guide to the Low-Income Housing Tax Credit, including the 4% vs 9% credit structure.