The solar investment tax credit for businesses in 2026 is claimed through Section 48E at a 30 percent rate for projects meeting labor requirements. This guide explains how companies actually claim it, how it pairs with depreciation, and the recapture risk that can claw the credit back.
- Businesses claim the solar ITC through Section 48E, the technology-neutral successor to the old Section 48 credit, at 30 percent for labor-compliant projects.
- The credit offsets income tax dollar for dollar and pairs with five-year MACRS depreciation for a combined value near half the project cost.
- Companies without enough tax liability can transfer the credit, use tax-equity partnerships, or carry it forward.
- Recapture can claw back the credit if the system is sold or stops qualifying within five years.
- Every structure here is tax-sensitive. Confirm the plan with a tax professional before signing contracts.
What the Business ITC Is in 2026
The business solar investment tax credit most owners remember, the old 30 percent Section 48 ITC, was replaced for new projects by Section 48E, the clean electricity investment credit. For solar projects placed in service from 2025 onward, 48E is the credit that matters. Functionally it works the way the old ITC did: a credit equal to a percentage of the eligible project cost, subtracted directly from the company’s income tax bill.
The rate is 30 percent for projects that meet prevailing wage and apprenticeship requirements, or for small projects under 1 MW AC that are exempt from those rules. Without the labor compliance, the rate drops to 6 percent on larger projects, which is why every serious commercial proposal in 2026 is built around the 30 percent figure. Bonus adders for domestic content, energy communities, and qualifying low-income projects can add 10 to 20 percentage points more. Our 48E credit guide details each adder and its eligibility rules.
How Companies Claim the Credit
Claiming the credit happens on the tax return, not through an application portal. The company that owns the system, and placed it in service during the tax year, files the federal energy credit forms with its return and applies the credit against its income tax liability. Unused credit can generally be carried forward to future tax years within statutory limits, which helps companies whose liability in the placed-in-service year is smaller than the credit.
Timing drives everything. The credit belongs to the tax year the system is placed in service, meaning operational and interconnected, not the year construction started or the deposit was paid. A project that slips from December to January moves a large credit into the next tax year, which can matter for cash planning. Developers and tax advisors should put the placed-in-service definition in writing early, because construction schedules, utility interconnection queues, and tax filings all run on slightly different clocks. The IRS publishes the forms and instructions; your CPA should be the one interpreting them for your entity type.
Pairing the Credit With Depreciation
The credit gets the headlines, but depreciation quietly contributes a large share of the total tax value. Commercial solar equipment is generally classified as five-year property under MACRS, so the company deducts the depreciable basis on an accelerated schedule over six tax years. Bonus depreciation, when available at high percentages, pulls much of that deduction into year one. Bonus rules have changed repeatedly through legislation, so verify the current percentage rather than assuming the old 100 percent figure.
Here is a modeled example to show the stacking. A $400,000 commercial rooftop project qualifies for the 30 percent credit, worth $120,000. The depreciable basis, reduced by half the credit under the basis-reduction rule, is $340,000. At a 25 percent combined tax rate, depreciation deductions on that basis are worth roughly $85,000 in present value. Total tax value: about $205,000, or just over half the installed cost. Then the electricity savings start, on a system the company effectively bought for half price. This is the math that makes commercial per-watt pricing look so different after incentives than before.
| Tax benefit | Mechanism | Modeled value on $400,000 project |
|---|---|---|
| 48E investment credit | 30% of eligible cost, dollar-for-dollar against tax | $120,000 |
| MACRS depreciation | 5-year property; deductions at the company’s tax rate | ~$85,000 present value |
| Combined tax value | Credit plus depreciation | ~$205,000 (about 51% of cost) |
Structures for Companies Without Tax Appetite
Not every business can use a $120,000 credit. Startups with no profits yet, pass-through owners with low personal liability, and nonprofits with no tax bill at all need different structures. Three exist. First, credit transfer: the owner sells the credit to an unrelated buyer for cash, typically at a discount of 5 to 15 percent of face value. Transfer deals have minimum efficient sizes because of legal and transaction costs, usually making sense above a few hundred thousand dollars of credit value.
Second, tax-equity partnerships: an investor with tax appetite funds part of the project in exchange for the credits and depreciation, with the business buying power or leasing the system. These are standard in large commercial and community solar but heavy for a 50 kW rooftop. Third, third-party ownership: a developer owns the system outright, claims everything, and sells the business power through a PPA or lease. The business gets savings with no tax complexity and no upfront cost. Our commercial financing guide compares these paths, and the Department of Energy publishes explainers on commercial solar finance structures.
Recapture: How the Credit Gets Clawed Back
Recapture is the rule most often skipped in sales presentations. If the business disposes of the system, or it stops being qualifying property, within five years of being placed in service, the IRS recaptures a portion of the credit. The recapture percentage steps down over the five-year window: 100 percent in year one, declining to 20 percent in year five, then zero afterward. Sell the building with the system in year three and a meaningful slice of the credit comes back as additional tax.
This has practical consequences. If you might sell the property within five years, structure the transaction so the buyer assumes the system properly, or model the recapture cost into the sale price. If the system is destroyed, insurance proceeds and casualty rules interact with recapture in technical ways your advisor should map in advance. Leasing the building to a tenant does not by itself trigger recapture as long as the owner keeps the system in qualified use, but sale-leasebacks and ownership changes need review. The five-year clock is the reason experienced developers call the credit “earned over five years” even though it is claimed in year one.
Common Mistakes That Cost Real Money
The most expensive mistake is assuming the credit without confirming labor compliance. A 1.5 MW project that misses the apprenticeship percentage can fall from 30 percent to 6 percent, erasing hundreds of thousands of dollars. Get the compliance plan in writing from the EPC contractor and keep payroll records. The second mistake is basis errors: land, building upgrades, and financing costs generally do not count toward eligible basis, and inflating basis invites penalties.
The third mistake is passive-activity limitations for individual investors in partnerships, which can defer credit use in ways that surprise first-time solar investors. The fourth is forgetting state interaction: some states conform to federal treatment and others do not, and state credits may have their own recapture rules. Verify everything at dsireusa.org and with counsel licensed in your state. None of these are reasons to avoid the credit. They are reasons to build the project team, installer, tax advisor, and attorney, before the first panel is ordered.
Can I claim the business ITC if I lease my building?
Generally the system owner claims the credit. If you lease the building but own the solar system, you can typically claim it. If the landlord owns the system, the landlord claims it. Get the ownership allocation in writing in the lease.
How is the business ITC different from the residential credit?
They are separate sections of the tax code. The residential 25D credit ended for systems installed after December 31, 2025. The business credit under 48E continues, adds depreciation pairing that homeowners do not get, and has labor and recapture rules homeowners never faced.
Can nonprofits use the solar tax credit?
Tax-exempt entities generally cannot use tax credits directly, but direct pay provisions allow qualifying organizations to receive the credit value as a payment from the IRS. Municipalities, schools, and houses of worship have used this path. Confirm eligibility with a tax professional.
What triggers ITC recapture?
Selling the system or ceasing qualified use within five years of the placed-in-service date. The recapture rate declines from 100 percent in year one to 20 percent in year five. Plan property sales and ownership changes around this clock.
Should I transfer my credit or use tax equity?
Transfer is simpler and cheaper for mid-size projects, usually at a 5 to 15 percent discount to face value. Tax equity suits larger projects where the complexity cost is justified. Both need professional structuring; neither is a DIY decision.
Ready to compare real solar prices?
Get free, no-pressure quotes from vetted local installers and see what solar costs for your roof.
