USA Solar Energy Market Study 2026–2031

Financial Model, Renewable Energy, Solar

Financial Modeling, Financial Planning, Free Financial Model Templates, Market Studies, PDF

A 46-page USA solar PV market study built for financial modelers, IPP developers, and infrastructure analysts who need to calibrate deal assumptions through the post-OBBBA tax-credit sunset. Covers all four PV segments — utility-scale ground-mount, C&I distributed generation, residential rooftop, and community solar — with quantified 2026–2031 scenarios, ISO-level capture-rate analysis across CAISO / ERCOT / MISO / SPP / PJM / NYISO / ISO-NE, and a full post-OBBBA bankability framework that links the 7 July 2026 begin-construction (BOC) cliff, the 31 December 2027 placed-in-service (PIS) sunset, FEOC Material Assistance Cost Ratio (MACR) compliance, and transferability discount propagation into PPA pricing.

Key findings

• End-2025 installed capacity: the United States closed 2025 with 279 GW-DC across all four PV segments (SEIA / Wood Mackenzie) — equivalent to roughly 220 GW-AC of utility-scale operating capacity on the federal EIA convention. The DC vs AC convention drives more than a 10% headline gap and is restated at every first use in the study.
• 2025 was a contraction year — 2026 reverses it sharply: SEIA reports 43.2 GW-DC of additions in 2025, −14% YoY, on permitting and tariff drag. EIA STEO forecasts 43.4 GW-AC of utility-scale solar in 2026 — a +60% year-on-year jump — as developers race the 7 July 2026 BOC cliff.
• The post-OBBBA bankability cliff: the One Big Beautiful Bill Act (H.R. 1, 4 July 2025) terminates §48E ITC and §45Y PTC for solar placed in service after 31 December 2027 unless construction begins by 7 July 2026 (in which case the safe-harbor PIS deadline extends to 31 December 2030). IRS Notice 2025-42 (15 Aug 2025) tightened physical-work and 5% safe-harbor tests post-OBBBA.
• FEOC Material Assistance Cost Ratio (MACR): IRS Notice 2026-15 (12 Feb 2026) sets the 2026 BOC thresholds at 40% for qualified facilities, 55% for storage, and 50% for components — ratcheting upward in subsequent years. Project economics now turn on documented non-FEOC sourcing.
• National LCOE: LBNL’s Utility-Scale Solar 2025 reports $60/MWh national LCOE without credit and $41/MWh with the ITC on 2024-vintage projects. 2025 vintage will run 5–10% higher post-tariff and post-OBBBA cost of capital.
• ISO PPA price bands diverge: CAISO and non-ISO West clear at ~$20–30/MWh for utility-scale solar (2024 vintage LBNL data); ERCOT clears at ~$45–55/MWh; the Northeast clears highest at $60–80/MWh.
• Three quantified 2031 scenarios: Bear 25% / Base 55% / Bull 20% subjective probability split. Base case reaches 560–620 GW-DC by end-2031 (midpoint 590 GW-DC) — cited as a range per skill §2.3.1 because cross-source divergence exceeds 10% across EIA AEO, SEIA, and BNEF trajectories.
• Top-5 utility-scale developers — NextEra, AES Clean Energy, Invenergy, Clearway Energy, and EDF Renewables — control roughly 20–25% of operating utility-scale capacity. The full top-10 table in §9 cross-references EIA Form 860M Q1 2026, Solarplaza 2025, and corporate disclosures.

Three quantified 2031 scenarios

The study presents three forward scenarios with subjective probabilities summing to 100%, calibrated against EIA AEO 2026 reference case, SEIA / Wood Mackenzie trajectory, and BNEF 1H 2026 outlook.

Bear — 25% probability — ~470 GW-DC by end-2031. OBBBA strict enforcement: IRS interprets BOC test narrowly, FEOC MACR climbs steeply, transferability discount widens to 12–15%. CA Supreme Court upholds NEM 3.0; PJM 2027/28 BRA result not repeated. Annual additions compress to ~40 GW-DC by 2030. Utility-scale PPAs rise 15–20% nationally.

Base — 55% probability — 560–620 GW-DC by end-2031 (midpoint 590 GW-DC). OBBBA with safe-harbor: most developers stockpile equipment + commence physical work by 7 July 2026, qualifying for the 12/31/2030 PIS extension. FEOC MACR thresholds met via domestic + India + South Korea sourcing. Transferability discount stabilizes 7–10%. Annual additions average 50–55 GW-DC.

Bull — 20% probability — ~650 GW-DC by end-2031. Partial OBBBA rollback: 2027 election shifts Treasury interpretation; CA Supreme Court remands NEM 3.0; FERC Order 1920 accelerates RTO transmission. Hyperscaler PPA volume surges on AI data-center load. Annual additions average 60+ GW-DC.

Probability-weighted 2031 expected value: ~565 GW-DC.

What’s inside

• Title page + Table of Contents (locked EFM specification).
• Executive Summary with 10 key points addressing all six user-priority questions.
• 14 body chapters: §1 Methodology · §2 The Industry Today · §3 Supply-Side Analysis · §4 Demand-Side Analysis (incl. §4.5 US Module Manufacturing & 45X) · §5 Pricing · §6 Three Scenarios · §7 Technology · §8 Regulatory + §8.X Post-OBBBA Bankability Framework · §9 Competitive Landscape · §10 Best Practices · §11 Risks · §12 Recommendations · §13 Sources · §14 Glossary.
• 3 appendices: Appendix A — Scenario sensitivity tables (BOC date sensitivity 2026/2027/2028 variants; transferability discount 5–15% sensitivity; FEOC compliance cost) · Appendix B — Quick-Reference Modeler Action Checklist · Appendix C — Disclaimer.
• 12 EFM-branded charts: installed capacity by segment 2020–2025; cumulative trajectory 2026–2031 three scenarios; ISO PPA price bands; LCOE bridge with/without ITC + adders; FEOC MACR cost ladder; transferability discount trajectory; top-10 developer share; interconnection queue by ISO; net AC capacity factor by latitude; OBBBA BOC + PIS timeline; state regulatory crosswalk; risk heatmap.
• 13 data tables including 22-instrument regulatory sweep, top-10 developer roster with operational + pipeline GW, ISO capture-rate trajectory 2026–2031, capex per Wdc composition, and scenario sensitivity matrix.
• 42 cited sources verified in the companion Source Verification workbook — including federal regulators (EIA, FERC, BLM, DOE LPO, IRS, DOC, USTR), institutional analysts (LBNL, NREL, IEA), industry associations (SEIA, ACORE), market-data analysts (Wood Mackenzie, BNEF, Crux Climate, Solarplaza, S&P Global), trade press, and corporate filings.

Audience

Primary: Financial modelers and buy-side / sell-side equity and credit analysts calibrating USA utility-scale and DG solar deal assumptions. Includes valuation / M&A advisors, infrastructure debt analysts, and modeling consultants.

Secondary: Independent power producer (IPP) developers and infrastructure equity investors evaluating greenfield, brownfield, and M&A opportunities in USA solar.

Tertiary: Corporate PPA off-takers (hyperscalers, manufacturing, retail), federal and state regulators, energy-economics graduate programs, sell-side consultants.

Data sources

Federal regulators and statistical agencies: US Energy Information Administration (EIA Forms 860, 860M, 861; STEO; AEO 2026), Federal Energy Regulatory Commission (FERC State of the Markets; Order 2023 / 2023-A; Order 1920; Form 1), IRS (Notices 2025-42 and 2026-15), Department of Commerce (AD/CVD), USTR (Section 201), Bureau of Land Management (Western Solar Plan), Department of Energy Loan Programs Office.

Institutional analysts: Lawrence Berkeley National Laboratory (Utility-Scale Solar 2025; Tracking the Sun 2025; Queued Up 2025), National Renewable Energy Laboratory (Annual Technology Baseline 2025; Spring 2025 Solar Industry Update), International Energy Agency (Renewables 2025).

Market-data analysts: Wood Mackenzie (US Solar Market Insight via SEIA partnership), BloombergNEF (1H 2026 US Renewable Energy Outlook + 2026 Sustainable Energy in America Factbook with BCSE), Crux Climate (transferability market tracker), Solarplaza (developer rankings), S&P Global Market Intelligence.

Industry associations: Solar Energy Industries Association (SEIA — US Solar Market Insight; Solar Means Business 2025), American Council on Renewable Energy (ACORE policy briefs).

ISO / RTO regulators: MISO LRTP Tranche 2.1, PJM 2027/28 BRA, SPP Consolidated Planning Proposal, CAISO + ERCOT + NYISO + ISO-NE compliance filings.

State regulators: MA DOER (SMART 3.0), NJ BPU (SuSI Aug 2025 Order), NY DPS (NY-Sun + CLCPA), CPUC (NEM 3.0 / Net Billing Tariff), TX PUC (SB 2627 / HB 1500 Texas Energy Fund).

Trade press: pv magazine USA, PV-Tech, Utility Dive, Reuters Energy.

Corporate filings: NextEra Energy, AES Corporation, Clearway Energy, EDF Renewables, Invenergy, Lightsource bp, Engie North America, Brookfield Renewable, Ørsted, RWE Clean Energy.

Methodology

This study was produced under the eFinancialModels Market Study production protocol (skill v1.7). The protocol mandates a three-phase intake — Question Analysis (18 questions in 9 clusters), Clarification, and Competitive Research with an 18-month regulatory sweep (22 instruments captured Nov 2024 → May 2026) — before drafting begins. Every chart and table is cited inline. Headline-number contradictions across analyst sources are reconciled in an internal table and cited as ranges in the .docx where divergence exceeds 10%. Material single-source claims are visibly labeled per skill §7 step 6. The full source-verification workbook is available alongside this study; every formal source (50 entries) and every inline fact (35 entries) is mapped to a verification flag.

The study uses both GW-DC (SEIA / BNEF / industry convention) and GW-AC (EIA / FERC / LBNL convention) — convention restated at every first use; conversion ratio 1.27 (LBNL 2025 fleet median). Geographic taxonomy is split per-purpose: ISO/RTO level for wholesale market dynamics, transmission, capacity markets, PPA pricing, and curtailment; state-level for DG / NEM / land-use / RPS / retail rates; national for federal tax credits, OBBBA, and FEOC compliance.

eFinancialModels uses AI-assisted research and drafting tools as part of its market-study production methodology, alongside human research, source verification, and editorial review. Every claim, statistic, source, chart, and recommendation was reviewed and verified by the eFinancialModels editorial team before publication. AI tools accelerate research and drafting; we do not publish unverified content.

Build a financial model that uses these inputs

The matching paid template is the EFM Utility-Scale Solar PV Financial Model — a structured Excel workbook covering revenue (PPA + merchant + capacity + REC stacks), CapEx and 45X / domestic-content adders, OBBBA tax-credit monetization (ITC vs PTC vs transferability), debt sizing, FEOC compliance modeling, and three-statement output for a US utility-scale solar project.

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FAQ

What does the OBBBA Section 48E and Section 45Y sunset mean for my model?

The One Big Beautiful Bill Act (H.R. 1, 4 July 2025) terminates the §48E ITC and §45Y PTC for solar and wind facilities placed in service after 31 December 2027 — unless construction begins by 7 July 2026, in which case the placed-in-service deadline extends to 31 December 2030. For financial modelers, BOC date is now the single most important sensitivity variable. The study’s Appendix A provides BOC date sensitivity for 2026 / 2027 / 2028 vintages.

How do FEOC MACR thresholds affect project economics?

IRS Notice 2026-15 (12 February 2026) sets the 2026 BOC FEOC Material Assistance Cost Ratio at 40% for qualified solar facilities, 55% for storage, and 50% for components. Thresholds ratchet upward in subsequent years. Failure to satisfy the MACR disqualifies the project from §48E / §45Y. The study quantifies the cost premium of FEOC-compliant sourcing in §8.X and Appendix A.

What ISO has the cheapest solar PPAs in 2026?

CAISO and non-ISO West clear at approximately $20–30/MWh on 2024 vintages (LBNL Utility-Scale Solar 2025). ERCOT clears at approximately $45–55/MWh. PJM and MISO mid-pack. The Northeast (NYISO, ISO-NE) clears highest at $60–80/MWh. The study’s §5 maps full ISO-level bands with cannibalization trajectories through 2031.

What is the transferability discount and how do I model it?

Tax-credit transferability under IRC §6418 allows project owners to sell tax credits to unrelated buyers at a discount (cents on the dollar). Crux Climate’s transferability tracker shows discount ranges of 5–15% depending on counterparty tier (investment-grade corporate buyers transact at tighter discounts than first-time tax-credit buyers). The study’s §6 and §8.X quantify how the discount propagates into PPA pricing and project IRR.

Which developers should I benchmark against?

The study names the top-10 utility-scale developers in §9 with operational + pipeline GW: NextEra Energy, AES Clean Energy, Invenergy, Clearway Energy, EDF Renewables, Lightsource bp, Engie North America, Brookfield Renewable, Ørsted Onshore North America, and RWE Clean Energy. Each profile draws from EIA Form 860M Q1 2026, Solarplaza 2025, and corporate disclosures.

Are P50 / P90 capacity factors covered by ISO?

Yes. Appendix A provides net AC capacity factor benchmarks by ISO and by latitude, with P50 / P90 ranges, curtailment haircuts (heaviest in ERCOT West Texas and CAISO mid-day), and capture-rate haircuts in oversupplied zones. LBNL’s fleet weighted-average is 23.6% AC (2024 vintage); the appendix provides the band around it.

How are scenarios defined?

Three forward scenarios with subjective probabilities summing to 100%: Bear 25% (OBBBA strict enforcement), Base 55% (OBBBA with safe-harbor), Bull 20% (partial OBBBA rollback). Each scenario quantifies cumulative GW-DC by 2031, weighted-average PPA prices, transferability discount, and developer IRR. See §6 and Appendix A.

Is this study citable in regulatory filings?

The study cites only verifiable institutional sources — every claim is mapped to a primary regulator, peer-reviewed national-lab publication, industry-association data product, or named market-data analyst. The companion Source Verification workbook (also free) provides URL-level traceability for every formal source and every inline fact.

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