Solar IRA Tax Credits in the US: Complete Guide for Installers (2026)

The federal solar tax credit picture changed fundamentally on January 1, 2026. The Section 25D residential credit — the 30% incentive homeowners had claimed since 2006 — expired. The Section 48E commercial Investment Tax Credit remains active at 30% and can reach 70% with bonus adders. For US solar installers, understanding exactly which credit applies to which project type, and how to maximize it, is now the difference between closing a commercial deal and walking away empty-handed.

The 2026 Solar Tax Credit Landscape: What Changed

The Inflation Reduction Act, signed August 16, 2022, created the most expansive solar incentive framework in US history. It extended and expanded the residential 25D credit, introduced technology-neutral clean energy credits, added bonus adder stacking, and opened transferability for the first time.

The One Big Beautiful Bill, signed July 4, 2025, accelerated several expiration dates. The most significant change for residential solar installers: the 25D residential credit was cut to expire at midnight December 31, 2025 — nine years ahead of the original 2032 IRA schedule.

Three other critical changes took effect in 2026:

1. Section 48E replaces Section 48. Projects placed in service after December 31, 2024 now fall under the technology-neutral Clean Electricity Investment Tax Credit rather than the technology-specific Section 48 credit. The structure is similar but the eligibility criteria differ.

2. FEOC restrictions activated. Projects beginning construction after January 1, 2026 face Foreign Entity of Concern material assistance restrictions. Any project where more than the allowable threshold of components originates from entities connected to China, Russia, Iran, or North Korea loses credit eligibility.

3. July 4, 2026 construction deadline. Projects must begin construction by July 4, 2026, or be placed into service by December 31, 2027, to qualify for the Section 48E ITC. This is a hard deadline — projects that miss it do not qualify for successor credits.

Section 25D vs. Section 48E: Side-by-Side Comparison

Understanding which credit applies to a given project is the first question any installer must answer.

The expiration of 25D does not eliminate solar incentives for residential installers — it shifts the mechanics. Homeowners using cash or loans to own their systems no longer qualify for a federal credit. Homeowners using leases or power purchase agreements benefit indirectly because the TPO operator claims the 48E credit.

Section 48E: How the Active Credit Works

Section 48E is a technology-neutral credit that covers any facility with an anticipated greenhouse gas emissions rate of zero — solar, wind, storage, and other clean generation all qualify.

For solar installers, the practical implications are:

Who claims it: The business, organization, or individual that owns and operates the system. In commercial installations, this is typically the business owner or a tax equity investor. In third-party residential, it is the leasing company.

What costs qualify: The full eligible basis includes solar PV panels, inverters, racking, wiring, labor for installation and site preparation, permitting fees, interconnection costs, and battery storage with a minimum capacity of 3 kWh. Soft costs (surveys, engineering) qualify when directly related to the installation.

Credit timing: The credit is claimed for the tax year in which the system is placed in service, not when construction begins or costs are incurred.

Carryforward: If a taxpayer’s credit exceeds their tax liability in the year the system is placed in service, the unused portion carries forward to future tax years.

Credit Rate Structure

The 24-percentage-point gap between 6% and 30% for large projects makes prevailing wage compliance a financial decision, not just a regulatory one. On a $5M commercial installation, the difference is $1.2M in credits.

What the 48E Phase-Out Schedule Looks Like

Under the current law, 48E credits for projects placed in service follow this schedule:

Projects placed in service in 2028 and beyond face a reduced base rate. The urgency to begin construction before July 4, 2026, and complete by December 31, 2027, is real.

Prevailing Wage and Apprenticeship Requirements

For projects at or above 1 MW AC, meeting prevailing wage and apprenticeship (PWA) requirements is the difference between a 6% credit and a 30% credit. Every installer working on projects in this size range needs to understand both requirements.

Prevailing Wage

All construction, alteration, and repair work on the project must be performed at or above the prevailing wage rate for each worker classification, as determined by the Department of Labor. These rates are published on the DOL’s SAM.gov wage determination database and vary by county and trade classification.

Who this covers: Every worker on site during construction — including subcontractors. The general contractor is responsible for ensuring subcontractors meet prevailing wage requirements. Wages must remain at prevailing rates during the 5-year period after the system is placed in service for any repair or alteration work.

Documentation: Certified payroll records for every worker, every pay period, for the entire construction duration. Installers should establish this documentation system before the first worker arrives on site.

Cure provision: If prevailing wage requirements are not initially met, they can be corrected by paying the difference to affected workers plus a 5% interest penalty, provided the failure was not intentional. An intentional disregard of requirements triggers a higher penalty and potential loss of the credit.

Apprenticeship Requirements

For projects beginning construction on or after January 1, 2024, at least 15% of total labor hours must be performed by registered apprentices from a DOL-registered apprenticeship program. This applies to all construction work, including subcontractors.

Good faith exception: If a taxpayer demonstrates it made good-faith efforts to hire apprentices from a registered program — including requesting apprentices from multiple programs and being turned down — the apprenticeship requirement may be waived.

Bonus Adders: Stacking Up to 70%

The IRA introduced four bonus adder categories that stack on top of the base Section 48E credit. A project that qualifies for all adders can reach 70% total ITC value — more than double the standard 30%.

Domestic Content Adder (+10%)

A 10% bonus (or 2% for projects at the 6% base rate) for projects where qualifying domestic content requirements are met.

For 2026 construction starts:

• All steel and iron components must be 100% produced in the United States
• 50% of the total cost of all other manufactured components must come from US-produced goods

This 50% threshold increases by 5 percentage points each year (55% for 2027, 60% for 2028, up to 65%).

Practical impact: Most Chinese-manufactured solar panels do not qualify. US-manufactured panels from brands like First Solar (Series 7 manufactured in Ohio) do qualify. Racking systems, inverters, and balance of system components must be sourced and documented accordingly.

The elective pay interaction: For tax-exempt entities using direct pay, failure to meet domestic content requirements results in a 10% credit reduction (for 2024 starts), 15% reduction (2025 starts), or full credit loss (2026+ starts). This is a harder requirement for direct pay filers than for standard taxable filers.

Energy Community Adder (+10%)

A 10% bonus for projects sited in an energy community — defined as one of three categories:

1. Brownfield sites: Former industrial or commercial land with potential or confirmed hazardous substance contamination
2. Statistical areas with fossil fuel employment: MSAs or non-MSAs where at least 0.17% of direct employment was in coal, oil, or natural gas extraction/processing
3. Census tracts with closed coal mines or coal plants: Including tracts that directly adjoin qualifying tracts

The DOE maintains an Energy Community Tax Credit Bonus mapping tool that allows installers to check whether a project address qualifies. The map updates annually.

Geographic overlap: Large portions of the Rust Belt, Appalachia, Wyoming, and Gulf Coast qualify as energy communities. Many suburban and rural commercial installations in these regions can claim this adder with no design modifications.

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

Two separate adders apply to qualifying low-income projects:

Both adders are limited to projects under 5 MW AC and require an annual capacity allocation from the Department of Energy (1.8 GW per year). Applications open annually and allocations are competitive — projects must apply and receive approval before claiming the adder.

How Adder Stacking Works

On a $10M commercial solar project that qualifies for all adders: a $7M tax credit against a $10M investment. The effective net cost drops to $3M before depreciation benefits.

FEOC Compliance: The Critical New Requirement for 2026

Foreign Entity of Concern restrictions are the most operationally disruptive change in the 2026 IRA landscape. Installers who do not adjust their supply chains now face losing credit eligibility on projects already under bid.

What Counts as a FEOC

A Prohibited Foreign Entity is any entity connected to China, Russia, Iran, or North Korea through one of these criteria:

• Headquartered in or incorporated under the laws of a covered country
• Majority-owned (25%+) by a covered country government or covered country entity
• Subject to direction from a covered country government

This covers not just equipment manufacturers directly but parent companies, subsidiaries, and joint ventures meeting the ownership threshold. The majority of global solar panel production falls within this definition.

How the Restriction Works

Projects lose Section 48E credit eligibility if the ratio of components from prohibited foreign entities exceeds the allowable threshold. For 2026 construction starts, the domestic content applicable percentage for qualified facilities is 50% — meaning more than 50% of component value must come from non-FEOC sources.

Treasury and IRS interim guidance issued February 12, 2026 provides specific procedures for calculating whether a project meets the material assistance thresholds.

Practical Equipment Implications

Documentation required: Installers must maintain supply chain documentation for all components — country of origin certificates, manufacturer declarations, and chain of custody records from distributor to installation.

MACRS Depreciation: The Hidden Multiplier

Most discussions of solar tax incentives stop at the ITC. For commercial clients, the Modified Accelerated Cost Recovery System (MACRS) depreciation benefit is nearly as valuable — and it stacks directly with the credit.

How Solar MACRS Works

Solar energy systems placed in service qualify for 5-year MACRS depreciation, allowing owners to recover their equipment cost over five tax years using an accelerated schedule:

The ITC Basis Adjustment

When an owner claims the ITC, the depreciable basis for MACRS is reduced by 50% of the ITC amount. This prevents double-dipping — you cannot depreciate the full cost of equipment that was partially funded by a tax credit.

Example calculation for a $1,000,000 commercial system in 2026:

For a business owner in a 37% tax bracket, that Year 1 MACRS deduction generates $113,220 in additional tax savings on top of the $300,000 ITC. Combined, they recover $413,220 of their $1M investment in the first year alone.

Bonus Depreciation in 2026

Bonus depreciation — which allows immediate expensing of a percentage of asset cost in the first year — is at 20% in 2026, down from 60% in 2024 and 40% in 2025. The schedule continues:

Projects placed in service in 2026 capture this 20% first-year expensing. Projects delayed to 2027 lose bonus depreciation entirely and rely solely on the 5-year MACRS schedule, reducing the first-year deduction from $306,000 to $136,000 in the example above.

Use SurgePV’s generation and financial tool to model these combined tax benefit scenarios for any project size. Running accurate financial projections that include ITC + MACRS is now a baseline expectation in commercial solar proposals.

Credit Monetization: Transfer and Direct Pay

The IRA introduced two mechanisms that fundamentally changed how solar tax credits flow through the market: transferability and direct pay.

Credit Transferability

Project owners who claim the Section 48E ITC can sell all or a portion of that credit to an unrelated third party for cash. The sale must occur by the tax return due date for the credit determination year.

How the market works: Tax credit buyers — typically banks, insurance companies, or large corporations with significant tax liability — purchase credits at a discount. Current market rates range from approximately $0.88 to $0.95 per dollar of credit, meaning a $3M credit can be sold for $2.64M to $2.85M in cash.

This eliminates the need for traditional tax equity partnership structures for project developers. Instead of a complex syndication arrangement, a developer can sell the credit outright in a straightforward transaction.

Key rules:

• The transfer is a one-time event — the credit cannot be further transferred by the buyer
• The transferee receives the credit at face value but cannot use it to offset self-employment tax
• The cash received by the transferor is not treated as gross income

Direct Pay (Elective Pay)

Non-taxable entities that previously could not benefit from tax credits can now receive them as direct cash refunds from the Treasury. Eligible entities include:

• State and local governments
• Tribal governments
• Rural electric cooperatives
• Tax-exempt organizations (501(c)(3))
• The Tennessee Valley Authority

For a county government installing a 2 MW solar array on a government facility, direct pay converts a $600,000 tax credit into a $600,000 cash payment from the IRS. This makes solar financially accessible to public sector clients who had no tax liability to offset.

The domestic content condition for direct pay: Projects with direct pay exceeding 1 MW must meet domestic content requirements or face a graduated penalty (10% reduction for 2024 starts, 15% for 2025 starts, full credit loss for 2026 starts).

This creates a compliance trap for public sector installers: a government building project using Chinese-manufactured panels could lose its entire direct pay claim. Equipment selection for public sector projects must now start with FEOC/domestic content verification.

Section 45Y Production Tax Credit: When It Beats the ITC

The IRA also introduced the Section 45Y Clean Electricity Production Tax Credit — the first time solar qualified for a PTC. For the right project, it outperforms the ITC.

How it works: Rather than a one-time credit based on installed cost, the PTC pays per kilowatt-hour of actual electricity generated for 10 years after the system is placed in service. The 2026 rate is approximately 2.6 cents/kWh.

When PTC > ITC:

For a utility-scale ground mount in a high-irradiance location (Arizona, New Mexico, Texas) with a capacity factor above 25%, a 10-year PTC stream often produces more total value than a one-time 30% ITC, particularly when the panels cost $0.25/W or less.

The same adders apply: Domestic content, energy community, and low-income adders stack on the PTC at the same rates (0.3 cents/kWh each for domestic content and energy community), though the low-income adder is ITC-only.

For solar installers designing projects above 5 MW, running both ITC and PTC scenarios in the financial model — factoring in expected generation, electricity rates, and expected holding period — is worth the analysis time.

How Installers Can Use IRA Credits as a Sales Tool

The ITC structure in 2026 creates specific sales opportunities that many installers are not fully using.

Commercial Solar Sales

For commercial clients with federal tax liability, the pitch is simple: the ITC directly reduces their tax bill dollar-for-dollar. Unlike a deduction (which reduces taxable income), a credit reduces the tax owed.

The effective cost calculation: A $500,000 commercial system generates a $150,000 ITC. If the owner is in the 37% bracket, that $150,000 credit is worth more than $240,000 in pre-tax earnings. In net present value terms — using the generation and financial tool to discount cash flows — many commercial systems achieve payback in 4-6 years even before factoring in utility rate escalation.

Bonus adder opportunity: Screen every commercial project address for energy community status before your first site visit. In large portions of the Midwest, Southeast, and Mountain West, this screen is quick and adds a 10% adder that costs nothing to claim. It directly reduces your client’s payback period.

Third-Party Ownership for Residential

The expiration of 25D eliminated the tax credit argument for homeowners who own their systems. But TPO models — leases and PPAs — remain viable because the installer or financing company claims the 48E credit.

The installer or their financing partner claims the 30% ITC, uses that to reduce the cost basis of the portfolio, and passes the savings to the homeowner through a lower lease payment or below-market PPA rate. The homeowner gets lower electricity bills without needing tax liability.

The installer’s role: Present the TPO option to residential customers who either lack sufficient tax liability to fully benefit from credits (retirees on fixed income, for example) or who prefer no upfront cost. A well-structured lease or PPA backed by the 48E credit can make residential solar installations cash-flow positive from month one.

Proposal Documentation

Any commercial solar proposal should include:

1. Gross system cost
2. ITC value (30% base + any applicable adders)
3. MACRS depreciation benefit (Year 1 + Years 2-6)
4. Net effective cost after credits and depreciation
5. Simple payback and NPV at current and projected utility rates
6. State incentive stacking (see next section)

Solar proposal software that automates this financial breakdown removes friction from the sales process. Clients who see the numbers clearly close faster than those who receive a single price quote.

For detailed guidance on structuring ROI-based commercial proposals, see our solar NPV, IRR, and payback guide.

State Tax Credits That Stack with the Federal ITC

Federal ITC and state-level incentives are generally stackable — claiming one does not reduce eligibility for the other. Several states have strong programs that significantly improve project economics.

The basis interaction: Some state rebates reduce the federal depreciable basis. When a state or utility pays a rebate directly to the system owner, that amount reduces the eligible cost for both the ITC and MACRS. Document whether rebates are taxable to the recipient and how they affect the ITC basis.

Sales tax exemptions in over 30 states do not affect the federal tax credit calculation and represent pure savings on top of the ITC.

For a comprehensive look at how US solar policy compares internationally, see European solar tax credits and incentives.

Documentation and Filing Guide

The Section 48E credit is claimed on IRS Form 3468. For residential TPO operators claiming 48E on residential portfolios, the process requires careful project-level tracking.

Timeline for Claiming the Credit

Form 3468 Requirements

Form 3468 requires:

• Description of the qualified investment credit property
• Placed-in-service date
• Eligible basis amount
• Applicable credit percentage
• Bonus credit calculations and documentation (domestic content, energy community)
• Prevailing wage certification (if applicable)
• Apprenticeship records (if applicable)

For domestic content adders, maintain: bill of materials with country of origin for all manufactured components, manufacturer certifications, and procurement documentation.

For energy community adders, document: the DOE energy community map screenshot at the time of project design, the project address, and any applicable census tract or MSA designation.

Record Retention

The IRS generally requires records for three years after filing, but credit records should be retained for as long as the credit can be subject to examination — which includes any carryforward years. For a credit that carries forward five years, retain records for at least eight years from the credit year.

The July 4, 2026 Deadline: What Installers Must Do Now

Every commercial project in your pipeline needs a construction start date audit against the July 4, 2026 deadline. Projects that miss this date lose 48E eligibility entirely — there is no grace period or extension mechanism.

The “begin construction” standard under IRS rules has two paths:

Path 1 — Physical work test: Physical work of a significant nature begins on site. This means actual installation activity — not planning, permitting, or procurement. Site preparation that is directly integral to the construction of the facility qualifies.

Path 2 — 5% safe harbor: At least 5% of the total project cost is paid or incurred before the deadline. This allows projects to lock in construction commencement through equipment procurement even if physical work has not started.

For a $2M project, spending $100,000 on panels or racking by July 3, 2026 satisfies the safe harbor and preserves eligibility through December 31, 2027 for placement in service.

Installer action items before July 4, 2026:

1. Audit all commercial projects in proposal, contract, or design stages
2. For projects unlikely to break ground by July 3, use the 5% safe harbor with documented equipment procurement
3. Establish start-of-construction documentation — signed contracts, purchase orders, site delivery receipts
4. For projects already under construction: document the construction start date and maintain contemporaneous records

See also: solar installation cost breakdown for a full breakdown of which cost categories count toward the 5% safe harbor basis.

Installer Profit Margins and the ITC’s Effect

The ITC does not directly affect an installer’s margins — it is the customer’s credit, not the installer’s. But it has a strong indirect effect on deal volume and project size.

In markets where the ITC is the primary financial driver for commercial clients, the tax credit effectively reduces the payback period from 8-10 years to 4-6 years. That reduction moves projects from “worth considering” to “obvious yes” for most business owners evaluating the investment.

For installers, this translates to higher close rates on commercial proposals, larger average system sizes as clients opt for maximum capacity given the improved economics, and less price sensitivity on equipment selection — clients who understand the credit math are less focused on minimizing upfront cost per watt.

For a detailed analysis of how US market dynamics affect solar installer economics, see solar installer profit margins.

Using solar design software that integrates financial modeling alongside design reduces the gap between the design conversation and the financial conversation. When a prospect sees the system layout, generation estimate, and ITC-adjusted payback on the same screen, the path to signature shortens.

Conclusion

Three actions every US solar installer should take now:

• Audit your commercial pipeline against July 4, 2026. Any project that misses the construction commencement deadline loses Section 48E eligibility entirely. Use the 5% safe harbor for projects at risk.
• Verify FEOC compliance for your equipment supply chain. Panels, inverters, and BOS components from Chinese manufacturers put 2026 construction starts at risk of losing credit eligibility. Build a FEOC-compliant sourcing list now.
• Add bonus adder screening to every commercial bid. Energy community status takes five minutes to check and adds 10% to the ITC at zero extra cost. Domestic content screening adds another 10% for projects using qualifying US-manufactured equipment.

The solar software and financial modeling tools that support accurate proposal generation are essential for communicating the true economics to commercial clients. In 2026, the difference between a 30% ITC and a 50% or 70% ITC is not marginal — it is often the difference between a project that gets approved and one that gets deferred.

Frequently Asked Questions

Did the solar tax credit expire in 2026?

The Section 25D residential credit for homeowner-owned systems expired on December 31, 2025, under the One Big Beautiful Bill. The Section 48E commercial and third-party ownership ITC remains active at 30% for qualifying projects placed in service before December 31, 2027.

What is the Section 48E solar tax credit?

Section 48E is the Clean Electricity Investment Tax Credit that replaced Section 48 for projects placed in service after December 31, 2024. It provides a 30% investment tax credit for commercial solar installations and business-owned residential systems that meet prevailing wage and apprenticeship requirements (or are under 1 MW AC).

How do solar installers qualify for the full 30% ITC in 2026?

Projects under 1 MW AC automatically qualify for the full 30% Section 48E credit. Projects at or above 1 MW must meet prevailing wage requirements for all construction workers and ensure at least 15% of labor hours are performed by registered apprentices to receive the full 30%. Without these requirements, the base rate is 6%.

What are ITC bonus adders and can they be stacked?

Yes, bonus adders are stackable. The domestic content adder adds 10%, the energy community adder adds 10%, and the low-income community or low-income residential adders add 10% or 20% respectively. A qualifying project can reach up to 70% total ITC by stacking all adders on top of the 30% base credit.

What are FEOC restrictions for solar in 2026?

Foreign Entity of Concern restrictions apply to solar projects beginning construction after January 1, 2026. Projects lose credit eligibility if more than the allowed threshold of components come from entities connected to China, Russia, Iran, or North Korea. For 2026 construction starts, the domestic content applicable percentage is 50% for facilities — meaning more than 50% of component value must come from non-FEOC sources.

Can homeowners still get a solar tax credit in 2026?

Homeowners who own their systems directly no longer qualify for a federal tax credit in 2026. However, homeowners using third-party ownership arrangements — leases or power purchase agreements — can still benefit indirectly, since the leasing company claims the Section 48E credit and passes the savings through lower payments.

What is direct pay for solar tax credits?

Direct pay (elective pay) allows non-taxable entities — state and local governments, tribal organizations, rural cooperatives, and nonprofits — to receive ITC and PTC as direct cash refunds rather than as tax offsets. This removes the need for tax equity financing for these entity types and opens the commercial solar market to public sector clients who previously had no tax liability to offset.

How does MACRS depreciation work alongside the ITC?

Commercial solar systems qualify for 5-year MACRS accelerated depreciation. When combined with the ITC, the depreciable basis is reduced by 50% of the credit taken. In 2026, 20% bonus depreciation applies, allowing owners to front-load depreciation on the adjusted basis. For a $1M system with a 30% ITC, this generates over $413,000 in combined first-year tax benefits — $300,000 ITC plus $113,000 in tax savings from Year 1 depreciation deductions at a 37% rate.