A US factory that ships 10 GWh of battery cells in 2026 can generate up to $350 million in federal tax credits. That is not a typo, and it is not a deduction—it is a dollar-for-dollar credit that can be sold for cash, used to pay quarterly estimated tax, or refunded directly to the producer for the first five years of operation. Section 45X, the Advanced Manufacturing Production Credit, has quietly become one of the most lucrative incentives in the federal tax code for companies that mine, refine, or assemble the parts of the clean energy supply chain.
But the rules just changed. The One Big Beautiful Bill Act (OBBBA), signed July 4, 2025, kept 45X alive while bolting on new guardrails: accelerated phase-outs for wind components and most critical minerals, sweeping Prohibited Foreign Entity restrictions, and a redefined "integrated component" rule that takes effect for tax years beginning after December 31, 2026. If your finance team has been operating on the old Inflation Reduction Act assumptions, your 2026 and 2027 returns are about to look very different.
This guide breaks down what 45X pays per unit, who can still claim it, how the OBBBA phase-out schedule works, and the documentation traps that can convert a $35-per-kWh windfall into a $35-per-kWh recapture event.
What Section 45X Actually Pays
Section 45X is a production tax credit. Unlike an investment credit, which rewards capital expenditure, the AMPTC pays you per unit of eligible component produced and sold to an unrelated person in the United States. The component categories and their statutory rates are:
Solar components
- Thin film or crystalline photovoltaic cell: $0.04 per watt of direct current (Wdc) capacity
- Photovoltaic wafer: $12 per square meter
- Solar grade polysilicon: $3 per kilogram
- Polymeric backsheet: $0.40 per square meter
- Solar module: $0.07 per Wdc
Wind components
- Offshore wind vessel: 10% of sales price
- Blade: $0.02 per watt of total rated capacity
- Nacelle: $0.05 per watt
- Tower: $0.03 per watt
- Offshore wind foundation (fixed platform): $0.02 per watt
- Offshore wind foundation (floating platform): $0.04 per watt
Inverters
Inverter credits range from $0.0025 per watt of AC capacity (central inverters) up to $0.11 per watt (microinverters), with utility, commercial, residential, and distributed wind variants in between.
Battery components
- Electrode active materials: 10% of production costs
- Battery cell: $35 per kWh of capacity
- Battery module: $10 per kWh (or $45 per kWh if the module does not use battery cells)
Critical minerals
A flat 10% of production costs for each of the 50 designated minerals, including lithium, cobalt, nickel, manganese, graphite, and—new under OBBBA—metallurgical coal.
The math gets large in a hurry. A gigafactory producing 30 GWh of battery cells at $35 per kWh generates $1.05 billion in gross credits before any module credit stacking. A solar module facility ramping to 5 GW per year at $0.07 per Wdc generates $350 million annually.
Who Qualifies
Three conditions must all be met before any credit is claimed:
- You produced the component. Mere assembly of foreign-manufactured subcomponents does not count. Treasury's final regulations require "substantial transformation" of inputs into the eligible component.
- The production occurred in the United States, Puerto Rico, or another US possession. Mexico and Canada do not qualify, even under USMCA.
- You sold the component to an unrelated person during the tax year. Related-party sales count only if the related party then sells to an unrelated end user (the "related party sales" election) and you file the required certification.
Contract manufacturing is allowed. If you operate a tolling arrangement where another company owns the raw materials and pays you to convert them into cells, the parties must sign a written certification (under penalty of perjury) designating which entity will claim the credit. Get this in writing before production starts. Disputes after the fact are nearly impossible to unwind because both parties typically want the same credit.
Direct Pay and Transferability
This is where 45X separates itself from most other business credits. Under Sections 6417 and 6418:
- Direct pay (Section 6417): For taxpayers that are not tax-exempt entities, a one-time election allows direct cash refunds of the 45X credit for five years from the year the election is first made. New ventures with no taxable income can convert the credit into working capital instead of carrying it forward.
- Transferability (Section 6418): Any taxpayer can elect to sell all or part of the credit to an unrelated buyer in exchange for cash. The cash is not taxable to the seller and not deductible to the buyer. Market pricing in 2025 has settled around 90 to 96 cents on the dollar for 45X credits, depending on credit quality, indemnification terms, and the seller's reputation.
OBBBA preserved both regimes for 45X, which is a significant win for the sector. Some other clean energy credits saw transferability windows narrowed.
To use either election, you must complete the IRS pre-filing registration portal and obtain a registration number for each eligible facility. The registration ID must appear on Form 7207 and any transfer election statement. Without it, the IRS will reject the election outright.
How to Claim the Credit
The mechanics live in Form 7207, Advanced Manufacturing Production Credit, which flows into Form 3800, General Business Credits, and then onto your income tax return.
A few filing rules trip up first-time claimants:
- One Form 7207 per facility. If you run a polysilicon line in Texas and a cell line in Tennessee, you file two separate Form 7207s, each with its own facility-level registration number.
- Pass-through entities file at the entity level. Partnerships and S corporations file Form 7207, then allocate the credit to partners or shareholders on Schedule K-1. Those partners report it directly on Form 3800 without re-filing Form 7207—unless the partner is itself a pass-through, in which case the cycle repeats.
- Direct pay must be elected on a timely-filed return. Late returns disqualify the election for the entire year. Extensions are allowed, but missed extension deadlines cannot be cured with a superseding return.
- Transfer elections require buyer information. The transfer election statement names the buyer, the credit amount transferred, and the consideration paid. Both parties retain copies; the IRS does not provide a separate confirmation.
Accurate bookkeeping from day one is non-negotiable here. The credit calculation traces back to per-unit production records, sale documentation, bill-of-materials cost detail, and—for the critical minerals 10% rate—a clean cost accounting system that distinguishes production costs from non-qualifying overhead. Plain-text accounting workflows that version-control these schedules make audit defense far simpler than reconstructing the trail from spreadsheets eighteen months later.
The OBBBA Phase-Out Schedule
Before OBBBA, 45X had a clean linear phase-out: most components stepped down to 75% in 2030, 50% in 2031, 25% in 2032, and zero after 2032. Critical minerals had no phase-out at all under the original IRA. OBBBA rewrote the schedule by component class.
Wind components — accelerated cliff
Wind sees the fastest exit. The credit is reduced to:
- 85% for components sold in 2026
- 90% for components sold in 2027
- 0% for components sold after December 31, 2027
If you operate a tower or nacelle line, the question is no longer "should I plan for 2032?" but "can I pull production into 2026 and 2027 to capture the residual?" Note that the percentages above multiply against the statutory rate—so a nacelle in 2026 earns $0.045 per watt rather than $0.05.
Solar, battery, and inverter components — original schedule preserved
Solar cells, wafers, modules, polysilicon, backsheet, inverters, battery cells, battery modules, and electrode active materials retained the original phase-out (100% through 2029, then stepping down to zero after 2032). This is a meaningful pro-solar and pro-battery outcome and is the reason most 45X-backed investments since July 2025 have concentrated in those categories.
Critical minerals — new long-tail phase-out
OBBBA introduced a phase-out for critical minerals that did not exist under the IRA. Production after 2030 earns:
- 75% in 2031
- 50% in 2032
- 25% in 2033
- 0% after 2033
Metallurgical coal — a new entrant on a short fuse
OBBBA added metallurgical coal (used in steelmaking) as a critical mineral, but only for production years 2026 through 2029. After December 31, 2029, the credit is gone. Met coal producers have a four-year capture window.
Prohibited Foreign Entity Rules: The New Compliance Layer
The biggest operational change is not the phase-out percentages—it is the Prohibited Foreign Entity (PFE) regime. Starting with tax years beginning after December 31, 2025, 45X eligibility requires that your component and your supply chain avoid material assistance from PFEs.
A PFE is either:
- A Specified Foreign Entity (SFE): entities tied to China, Russia, North Korea, or Iran, including those named under the Uyghur Forced Labor Prevention Act, or
- A Foreign-Influenced Entity (FIE): an entity where an SFE owns at least 25%, holds qualifying debt, has contractual control, or licenses critical IP with effective control rights.
The compliance test is the Material Assistance Cost Ratio (MACR). Your non-PFE direct material costs must exceed a phased threshold of total direct material costs:
- 2026: at least 50% non-PFE
- 2027–2028: at least 55% non-PFE
- 2029 and later: at least 60% non-PFE
If your battery cathode active material is supplied by an FIE—say, a Korean entity in which a Chinese SFE holds 30%—those costs count against you. Operations teams sourcing precursor materials, separators, or cell housings should be running supplier diligence now; rebuilding the supply chain mid-2026 to cure a failed MACR test is logistically painful and economically punishing.
The 2027 Integrated Component Rule
OBBBA added a related-party sales restriction that bites in tax years beginning after December 31, 2026. To claim credits on an integrated component (a primary component embedded into a larger secondary component within the same facility, like cells assembled into a module), at least 65% of the direct material cost of the primary component must come from US-mined or US-manufactured inputs.
This is layered on top of the MACR. You can satisfy MACR with 50% non-PFE material in 2026 but still fail the integrated-component test if your wafer-to-cell-to-module facility relies on imported polysilicon below the 65% threshold. The interaction is one of the most actively litigated areas in current tax planning, and Treasury is expected to issue clarifying guidance during 2026.
Five Mistakes That Cost Manufacturers Real Money
- Skipping pre-filing registration. No registration ID means no direct pay and no transfer. The IRS portal is not retroactive—register before the production year ends.
- Treating substantial transformation as a checkbox. Repackaging or simple kitting does not qualify. Final regulations specifically reject assembly of foreign-manufactured complete cells from being relabeled as US production. Get an opinion letter for borderline operations.
- Failing the contract manufacturing certification. Both the toller and the customer want the credit. If neither party can produce a signed penalty-of-perjury certification, the IRS denies both. File certifications contemporaneously, not when the audit notice arrives.
- Misclassifying production costs for the 10% critical minerals rate. Only direct costs (labor, materials, energy directly attributable to mining or refining) count. General SG&A, financing costs, depreciation on non-production assets, and intercompany markups are excluded. Misclassification at the top of a billion-dollar production cost base creates seven-figure adjustment exposure.
- Ignoring PFE refresh requirements. Supplier ownership can change mid-year. A supplier that qualified on January 1 may become an FIE in Q3 if a Chinese investor crosses the 25% threshold. Bake quarterly supplier attestations into contracts and procurement workflows.
Stacking 45X With Other Incentives
45X is the rare credit that stacks cleanly with most state and local incentives. State manufacturing investment credits, property tax abatements, training grants, and Department of Energy loan guarantees (including the Loan Programs Office Title 17 financing) do not reduce the 45X credit base. The notable exception is Section 48C, the Qualifying Advanced Energy Project Credit—a facility that received a 48C investment credit allocation for a specific component cannot also claim 45X on the same component produced at that facility. Most operators choose 45X for high-volume production lines and reserve 48C for upstream feedstock or specialty equipment.
What 2026 Action Looks Like
Three things to put on the calendar:
- Q2 2026: Complete IRS pre-filing registration for every facility you expect to claim against, even if production is months away. Registration backlogs grew throughout 2025.
- Q3 2026: Audit your supplier base against the 50% MACR threshold. Document non-PFE sourcing with bill-of-materials traceability. Begin renegotiating critical inputs that fail the test.
- Q4 2026: Decide on direct pay versus transferability. For pre-revenue or early-stage producers, direct pay almost always wins because the cash arrives roughly six months after the return is filed. For mature producers with tax appetite, transferability monetizes faster and avoids the five-year direct pay clock.
Keep Your Production and Tax Records Audit-Ready
Section 45X is a paperwork credit. Per-unit production logs, sale documentation, supplier attestations, and direct-cost ledgers will determine how much of your gross credit survives an IRS review. Beancount.io gives manufacturing finance teams a plain-text, version-controlled general ledger that traces production costs, intercompany transfers, and component-level sales without locking your data behind a proprietary database. Get started for free and keep your 45X documentation defensible from the first kilowatt-hour you ship.