Commercial Solar PPA vs. Direct Purchase vs. Capital Lease vs. C-PACE in California

The Deadline That Overrides Every Financing Decision

OBBBA rewrote Section 48E for solar and wind on a hard countdown. Facilities that began construction by July 4, 2026 are outside the new cutoff.

The statute's effective-date note applies the cutoff to facilities whose construction begins after "the date which is 12 months after" July 4, 2025, and IRS Notice 2025-42 read that as construction beginning after July 4, 2026.

Either way, that start-construction window has already closed — if your project's start date falls in that one-day gap, confirm the applicable cutoff with a tax advisor before relying on it. Anything beginning construction now falls under the harder rule: placed in service by December 31, 2027, or the credit is zero.

There's no multi-year phase-down cushion the way geothermal, storage, and some other clean-electricity technologies get through the early 2030s — for solar and wind, the credit just ends.

For a 100kW-2MW commercial rooftop project, that's roughly 16 months of runway from today, once you account for permitting, Rule 21 interconnection review, and equipment lead times. Whichever financing structure you choose, whoever owns the system for tax purposes needs to hit that in-service date to get anything.

If your realistic timeline runs past 2027, don't build your decision around a 30% credit that won't exist when the system goes live — price the project on its own economics instead.

Getting to the Full 30% — and Why the Safe Harbor Got Harder

The base 48E rate is 6%. For a facility of 1 MW AC or more, the full 30% requires meeting the prevailing-wage and apprenticeship requirements; a facility under 1 MW AC gets 30% regardless, under 26 U.S.C. §48E(a)(2).

That carve-out covers most commercial rooftop systems; above 1 MW AC, the full 30% depends on documenting actual compliance, or the credit drops back to the 6% base rate.

Establishing a construction-start date also got harder. IRS Notice 2025-42 made the 5% cost safe harbor unavailable for wind projects and for solar above 1.5 MW AC, and a federal court vacated that notice in full on June 6, 2026.

Only solar facilities of 1.5 MW or less that began construction before July 5, 2026 could still use the 5% safe harbor — a window that has now closed. Any commercial project starting construction today has to establish beginning-of-construction status through the "physical work of a significant nature" test instead, a higher documentation bar than writing a 5% deposit check.

A separate sourcing rule also applies: for construction beginning in 2026, at least 40% of system component value must come from non-prohibited-foreign-entity sources, rising 5 points a year toward 60% by 2030, and no specified or foreign-influenced entity can claim 48E at all.

The thresholds are in 26 U.S.C. §7701(a)(52); IRS Notice 2026-15 provides interim safe harbors for calculating the ratio. Ask your EPC for component sourcing documentation before signing anything.

Direct Purchase — You Own the Tax Benefits, and the Risk

Buy the system outright and you claim the 48E credit directly, plus the 100% first-year allowance §168(k) now provides for qualified property acquired after January 19, 2025. That lets you expense the entire depreciable basis at the federal level in year one. If you elect out of that allowance, §168(e)(3)(B)(viii) classifies §48E qualified property as 5-year property.

Once you're taking 100% bonus depreciation, the whole federal basis is expensed in year one regardless.

California doesn't conform to §168(k), though, according to the FTB's 2025 Form 100 booklet. You'll still be depreciating the asset on a normal schedule for state tax purposes, so talk to your CPA about the add-back before assuming the federal bonus depreciation number is your total benefit.

Direct purchase only pays off if your business has enough taxable income to use both the credit and the depreciation the year the system is placed in service — a business with thin or negative taxable income leaves both on the table.

PPA — Someone Else Owns the Tax Benefits, You Buy the Output

Under a PPA, a third-party developer or financier owns the system, claims the 30% credit and depreciation, and the per-kWh rate may reflect some of that value.

That's the mechanism that makes PPAs the default choice for nonprofits, schools, and any business without enough tax liability to use a credit directly — you can't waste a benefit you were never going to use.

This page does not repeat published commercial PPA price ranges, which are aggregator-sourced and blend deal types; ask any provider for a comparable, currently signed California commercial rate before treating a price as a benchmark. Get the escalator as a fixed percentage or a defined calculation method written into the contract, not open-ended language.

Buyout options usually appear at set contract years — push for a fixed-price schedule or a defined formula rather than "fair market value," since FMV at exercise time is a negotiated number, and you're rarely negotiating from strength years into a contract you didn't originate.

Capital Lease — Debt in Substance, and Now Debt on the Balance Sheet Too

Under ASC 842, a lease classifies as a finance lease (the current term for what used to be called a capital lease) if it trips any one of five tests — the one that matters most for solar is a purchase option your business is reasonably certain to exercise, which describes most solar capital leases with a bargain buyout built in.

Here's what changes the pitch: under ASC 842, unlike the prior ASC 840, both finance leases and true operating leases now go on the balance sheet as a right-of-use asset and a matching lease liability. The old "keep it off the balance sheet" sales argument for solar leases mostly disappeared when ASC 842 took effect in 2019.

What's left is an income-statement difference — a finance lease books separate interest and amortization expense, front-loaded like a term loan, while a true operating lease would show one smoother, straight-line expense. Because most solar leases carry a bargain purchase option, they classify as finance leases regardless of what the contract is titled.

Budget for it as debt, because your auditor will treat it as debt.

C-PACE — Financing Tied to the Property, Not the Business

Rates are lender-specific and move with the broader rate environment, so get a live quote rather than budgeting off a published range. Each administrator sets its own underwriting limits, such as how large the assessment can be against the property's value and how it combines with an existing mortgage; ask for them in writing. C-PACE is not available for single-family residential, condos, or government-owned buildings.

What Changes the Math: System Size, Utility, and the Battery Question

No primary source publishes California commercial installed prices by size tier.

LBNL's Tracking the Sun (2024 Edition) put 2023 installed prices for small non-residential systems (100 kWdc or less) at $2.50 to $4.30 per watt and for large non-residential systems (over 100 kWdc) at $1.70 to $3.10 per watt, 20th to 80th percentile, national, so per-watt prices fall as systems get larger.

If your business sits on PG&E, SCE, or SDG&E, you're on the Net Billing Tariff, approved by the CPUC December 15, 2022 and effective April 15, 2023, with export credits the CPUC says are usually lower than the retail rate.

The CPUC's early-adopter export adder applies to residential PG&E and SCE customers, not commercial accounts, which is why many commercial systems look at a battery to shift self-consumption rather than export.

The narrow safe-harbor window that let customers who filed a NEM 2.0 interconnection application before the April 14, 2023 NBT cutover still finish construction and lock in NEM 2.0 has now closed — Permission to Operate was required by April 15, 2026.

That path is unavailable for any new project signing today; it does not affect customers already grandfathered into NEM 2.0, who keep those terms for 20 years from their original interconnection date regardless.