Is Policy Risk Evolving for U.S. Solar?

The solar industry never fully escapes the shadow of Washington — but that shadow keeps changing shape. With the One Big Beautiful Bill Act now signed into law, many developers and investors exhaled, expecting at least a period of policy stability. That exhale may have been premature.

Analysts Jesse Pichel and Lev Seleznov of Roth Capital Partners are flagging two risks that deserve serious attention: the possibility of a second reconciliation bill reopening solar policy and persistent friction in tax equity and tax credit transfer markets driven by unresolved Foreign Entity of Concern (FEOC) and Prohibited Foreign Entity (PFE) guidance. Neither risk is theoretical. Both are actively shaping how capital flows into U.S. solar right now.

What the One Big Beautiful Bill Act Actually Did

The OBBBA represented a significant legislative moment for the clean energy sector — but its legacy is complicated. The bill adjusted the framework governing solar incentives in ways that were, depending on your position in the supply chain, somewhere between tolerable and painful.

The OBBBA didn't eliminate solar policy risk — it restructured it. Certain investment and production tax credit provisions were modified, timelines were compressed, and new qualification requirements introduced complexity for projects that were already mid-development. Developers who had structured financing around prior assumptions found themselves re-underwriting deals.

What the bill didn't do is settle the political debate. Reconciliation legislation, by its nature, passes on partisan lines and carries the implicit vulnerability of being revisited when political winds shift. The solar industry learned this the hard way through previous cycles — the boom-bust patterns driven by PTC expirations and extensions in the wind sector are a cautionary tale that solar investors would be wise to keep in their peripheral vision.

The Second Reconciliation Risk Is Real

The more immediate concern flagged by Roth Capital Partners is the prospect of a second reconciliation bill. This isn't speculative hand-wringing — reconciliation is a tool Congress uses with some regularity, and when a bill passes with provisions that leave constituencies dissatisfied, the mechanism to revisit those provisions exists.

For solar, that matters enormously. A second bite at the legislative apple could tighten incentive structures further, introduce new domestic content requirements, or accelerate phasedown schedules that developers are currently modeling as stable baselines. Projects with five-to-ten year development horizons — utility-scale solar, in particular — are especially exposed because their economic assumptions have to survive multiple election cycles.

Past reconciliation episodes reinforce the concern. The Inflation Reduction Act itself was a reconciliation bill, and watching how quickly political appetite shifted after the 2024 election cycle should remind the market that what Congress gives through one reconciliation process, it can modify through another. Institutional investors underwriting long-duration solar assets need to scenario-plan around this, not treat current law as a fixed ceiling.

Tax Equity and Transfer Markets Are Still Stuck

If the second reconciliation risk is a medium-term threat, the FEOC and PFE guidance problem is friction happening right now.

The Inflation Reduction Act opened up tax credit transferability — a structurally important change that was supposed to broaden the investor base for solar projects and reduce dependence on the narrow pool of traditional tax equity investors. In practice, it worked. The transfer market grew quickly and brought in corporate buyers who had never touched clean energy finance before.

But unresolved FEOC and PFE guidance has introduced uncertainty that is genuinely gumming up deals. The core issue is this: buyers of transferred tax credits need confidence that the credits they're purchasing are clean — that the underlying projects don't have disqualifying ties to foreign entities flagged by the U.S. government. Without clear, definitive guidance on exactly what constitutes a violation, buyers are applying their own risk tolerance, and that tolerance varies wildly.

Some credit buyers are walking away from deals with any Chinese supply chain exposure, even where the legal risk is arguably minimal. Others are demanding indemnification provisions that sellers find economically unworkable.

The result is a two-tier market. Projects with clean, domestically sourced supply chains are pricing their credits at a premium. Projects with any ambiguity — which, given global solar manufacturing realities, is a substantial portion of the market — are facing either significant discounts or outright buyer refusal. This is a real tax equity market disruption, not a paper risk.

For context, the traditional tax equity market for U.S. renewables has historically operated in the range of $20-25 billion annually. The transfer market was growing toward comparable scale. Any meaningful contraction in available financing at that magnitude has downstream effects on project timelines, developer balance sheets, and ultimately, megawatts built.

How Serious Investors Are Responding

The developers and investors navigating this environment well share a few common characteristics. They're not waiting for guidance to crystallize before acting — they're building legal and commercial structures that can accommodate multiple interpretations.

On the supply chain side, the best-positioned projects are those that started diversifying away from FEOC-adjacent manufacturers well before the political pressure peaked. That's a lesson with a long lead time: supply chain decisions made two or three years ago are determining financing options today.

On the policy risk side, experienced infrastructure investors are returning to fundamentals they've always applied to regulated industries. That means stress-testing project economics against scenarios where incentives are reduced by 25-50%, where phasedown timelines accelerate, and where new compliance requirements add cost. Projects that can't survive those scenarios on their underlying economics probably shouldn't be financed on the assumption that current policy holds indefinitely.

Diversification across geographies, off-take structures, and incentive dependencies has become a genuine risk management tool, not just a portfolio construction preference. Single-state, single-counterparty, single-incentive-dependent solar portfolios carry a concentration risk profile that's hard to justify in this environment.

Sophisticated credit buyers in the transfer market are doing more diligence than they were twelve months ago — full supply chain mapping, provenance documentation for modules and cells, and legal opinions on FEOC compliance. That due diligence infrastructure is expensive and slow, but it's becoming table stakes for large-scale credit purchases.

What the Market Looks Like From Here

The U.S. solar market is not in retreat. Demand for power — driven by data center load growth, industrial reshoring, and electrification — is creating a tailwind that no single piece of legislation is likely to fully offset. Utilities are signing long-term PPAs because they need the electrons, not because the tax incentives are attractive. That's a more durable foundation than the market had a decade ago.

But durable doesn't mean frictionless. The FEOC and PFE guidance issue will eventually resolve — either through formal rulemaking or through accumulated market practice and legal precedent that gives buyers enough confidence to transact. The question is how much capital sits on the sidelines and how many projects slip their COD dates waiting for that resolution.

The second reconciliation risk is the slower-burning concern. It's the kind of thing that doesn't affect day-to-day deal flow but absolutely affects how institutional investors think about terminal value and long-duration exposure. The project financed today may operate until 2055 — and the policy assumptions baked into that underwriting will be tested many times over.

What Roth Capital Partners is really signaling is that the solar industry has graduated from a world where the primary risk was whether incentives existed to one where the primary risk is whether those incentives are stable, defensible, and bankable. That's progress, of a complicated kind. The investors who recognize the distinction — and structure accordingly — will find opportunity where others see only uncertainty.

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