Solar CAPEX USA 2024 — PV Investment Costs by Region & State
This page presents U.S. solar photovoltaic CAPEX data across three segments: utility-scale, commercial, and residential. Utility-scale costs are broken down by ISO/RTO region (8 regions). Residential costs are shown by state. All figures are in $/Wdc (dollars per Watt DC), before federal incentives (ITC/PTC). Data compiled from NREL, LBNL and EIA institutional publications.
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1. NREL National Cost Benchmark ($/Wdc, Q1 2024)
NREL's PV System Cost Benchmark is the most widely referenced cost model in the U.S. solar industry. It uses a bottom-up methodology to estimate both the Minimum Sustainable Price (MSP, theoretical floor) and Market Median Price (MMP, actual market price including margins). The MMP is the relevant figure for financial modeling.
| Segment | Reference size | MSP ($/Wdc) | MMP ($/Wdc) | O&M ($/kWdc-yr) | LCOE ($/MWh) |
|---|---|---|---|---|---|
| Utility-scale | 100 MWdc | $0.98 | $1.12 | $19 | $47 |
| Commercial | 3 MWdc | $1.34 | $1.51 | $22 | $75 |
| Residential | 8 kWdc | $2.74 | $3.15 | $30 | $142 |
Source: NREL/DOE, "PV System Cost Benchmark: Q1 2024." MSP = Minimum Sustainable Price (theoretical cost floor). MMP = Market Median Price (actual market price — use this for financial models). All figures pre-incentive, excluding land.
2. Utility-Scale CAPEX by ISO/RTO Region ($/Wdc, 2024)
LBNL analyses real utility-scale project data from EIA Form 860 filings and aggregates costs by ISO/RTO region. This is the most granular publicly available data for U.S. utility-scale solar — state-level data is not published. Costs vary by 58% between the cheapest (ERCOT) and most expensive (NYISO) regions, driven by land costs, labor rates, interconnection queue delays, and local permitting.
Utility-scale CAPEX by ISO/RTO region — $/Wdc, 2024 projects (LBNL)
| ISO/RTO Region | Main states | $/Wac | $/Wdc (est.) | LCOE ($/MWh) | Confidence |
|---|---|---|---|---|---|
| ERCOT | Texas | $1.38 | $1.06 | ~$35 | Exact |
| Non-ISO West | AZ, NV, CO, UT, NM, OR, WA | ~$1.45 | ~$1.10 | ~$31 | Estimated |
| SPP | KS, OK, NE, parts of TX/LA | ~$1.55 | ~$1.18 | ~$40 | Estimated |
| MISO | IL, IN, MI, MN, IA, WI, MO | ~$1.60 | ~$1.22 | ~$45 | Estimated |
| CAISO | California | ~$1.70 | ~$1.30 | ~$50 | Estimated |
| PJM | PA, NJ, MD, VA, OH, KY, DE | ~$1.80 | ~$1.37 | ~$55 | Estimated |
| ISO-NE | CT, MA, ME, NH, RI, VT | ~$2.00 | ~$1.52 | ~$65 | Estimated |
| NYISO | New York | ~$2.20 | ~$1.67 | ~$77 | Estimated |
| National average | — | $1.61 | $1.22 | — | Exact |
Source: LBNL, "Utility-Scale Solar 2025 Data Update" (October 2025). COD 2024 projects. $/Wdc estimated using ILR ≈ 1.34. Values marked ~ are read from graphical data (±$0.05–0.10/Wac). ERCOT and national average are exact figures from the report. LCOE includes ITC at 30%.
3. Residential Solar CAPEX by State ($/W, 2023)
LBNL's Tracking the Sun database covers 3.7 million residential and commercial solar systems installed in the U.S. Unlike utility-scale data, residential costs are available at the state level. The range of $3.20–5.20/W reflects wide variation driven by local permitting costs, labor rates, installer competition, and customer acquisition costs.
Median cost ranges by segment
Source: LBNL Tracking the Sun 2024 (data through 2023). Ranges represent state-level variation across all reporting states.
Key cost drivers
Hawaii has a 95% battery attach rate; California 14%. Battery inclusion drives up median costs in these markets.
4. Economies of Scale — Cost by Project Size
LBNL data shows a strong inverse relationship between project size and per-watt cost. A 250+ MW project costs 37% less than a 5–20 MW project. This is one of the most significant cost drivers in U.S. utility-scale solar and explains why developers increasingly pursue very large projects.
CAPEX by project size — $/Wdc, 2024 projects (LBNL)
Larger projects benefit from bulk procurement, optimised logistics, and lower per-MW soft costs
| Project size | Cost ($/Wdc) | Premium vs 250+ MW |
|---|---|---|
| 5–20 MW | $1.62 | +47% |
| 20–100 MW | $1.53 | +39% |
| 100–250 MW | $1.28 | +16% |
| 250–800 MW | $1.10 | Reference |
Source: LBNL Utility-Scale Solar 2025 (2024 COD, $/Wdc). Cost reductions come from bulk procurement, optimised logistics, and lower per-MW soft costs.
5. IRA Tax Credits — Impact on Effective CAPEX
All CAPEX figures on this page are pre-incentive. The Inflation Reduction Act (IRA, August 2022) significantly reduces effective costs through a tiered tax credit structure. The base Investment Tax Credit (ITC) is 30% of qualified CAPEX, with stackable bonus adders:
A project qualifying for all adders could reach an effective ITC of 50–60%, reducing a $1.12/Wdc utility-scale project to an effective after-tax cost of $0.45–0.56/Wdc. However, qualifying for all adders simultaneously is difficult in practice.
Note: The IRA also offers a Production Tax Credit (PTC) as an alternative to the ITC, at $0.0275/kWh (2024 value, indexed to inflation). Developers choose whichever credit maximises value. PTC is typically more attractive for high-irradiance utility-scale projects.
Sources & Methodology
Data is compiled from the following U.S. federal institutional sources:
- → NREL PV System Cost Benchmark: Q1 2024 — bottom-up cost model, MSP & MMP, 3 segments (DOE/NREL)
- → LBNL Utility-Scale Solar 2025 — real project data, EIA Form 860, by ISO/RTO region (Oct 2025)
- → LBNL Tracking the Sun 2024 — 3.7M residential/commercial systems, by state (Aug 2024)
- → EIA Construction & Operating Costs — national averages by technology (2022 data, Nov 2024)
Methodology notes: All CAPEX in $/Wdc before federal incentives, excluding land. LBNL $/Wac values converted to $/Wdc using ILR ≈ 1.34. Regional estimates from LBNL graphical data have a margin of error of ±5–10%. NREL MMP reflects modeled market pricing, not a survey. EIA data is 2 years older than NREL/LBNL.
Values are indicative and do not constitute investment advice. Last updated: June 2026.