Commercial Solar AHJ Requirements by State
Table of Contents
The authority having jurisdiction (AHJ) is the local government body that reviews and approves permits for commercial solar installations. Requirements vary significantly by state and sometimes by county or municipality within a state. What passes in one jurisdiction can be rejected in the next.
Jolt Engineering has submitted commercial plan sets to AHJs across multiple states. This is a working guide to what AHJs require by state, including PE stamp requirements, common rejection reasons, and jurisdiction-specific details that are not always documented publicly.
How AHJ Requirements Work
The AHJ is typically a city or county building department, but it can also be a state agency or special jurisdiction (like a utility district or a tribal authority). For most commercial solar projects, the AHJ is the local building department.
What AHJ review covers:
- Structural compliance (building code, wind/snow loads, attachment requirements)
- Electrical compliance (NEC, local amendments)
- Fire code compliance (fire access clearances, NFPA requirements for BESS)
- Zoning compliance (setbacks, height, screening)
Utility interconnection is a separate approval process run by the utility, not the AHJ. Both approvals are required before a commercial system can be commissioned.
State-by-State AHJ Requirements
California
Governing codes: CBC (California Building Code), CEC (California Electrical Code, NEC-based), Title 24, NEM 3.0
PE stamp: Structural PE at 10 kW+; Electrical PE at 50 kW+. Some AHJs require SE (Structural Engineer) stamp for carport structures and seismic zones.
Interconnection: Rule 21 governs all utility interconnection. For commercial systems 25 kW to 1 MW, the fast track timeline is 4 to 12 weeks. Systems over 1 MW go through a more detailed study process.
Common rejection reasons:
- Customer-of-record mismatch on interconnection application
- Single-line missing NEC 2020 code references (California adopted NEC 2020 with state amendments)
- Fire access clearances not per IFC 1204 (AHJs enforce this strictly)
- Wrong SE credential on carport structures in seismic zones
Notable AHJs: LADWP and PG&E have their own interconnection portals and documentation requirements in addition to the local building department permit. Projects in their service territories need to account for both approval processes.
Arizona
Governing codes: Arizona State Building Code (IBC-based), NEC 2017
PE stamp: Required for all commercial solar, no size exemption.
Interconnection: APS, SRP, and TEP operate independently with different timelines and requirements.
- APS: 5 to 10 business days post-inspection for most commercial interconnections; $0.069/kWh RCP available
- SRP: Most rigorous process for systems over 20 kW; up to 7 to 14 business days for review after inspection
- TEP: Independent portal; $0.051/kWh export rate; typically 10 to 20 business days for commercial systems
Common rejection reasons:
- Missing SRP-specific documentation for systems over 20 kW
- Equipment not on APS or SRP approved lists (both utilities maintain their own)
- Wind uplift calculations not meeting local wind zone requirements (varies by county)
Texas
Governing codes: International Building Code as locally adopted; NEC as locally adopted. Significant variation by municipality.
PE stamp: No statewide mandate for commercial solar, but Oncor, CenterPoint, AEP Texas, and TNMP all require PE-stamped engineering documentation for interconnection approval. In practice, PE stamps are required.
Interconnection: Texas operates under ERCOT (most of the state) and MISO/SPP (eastern panhandle and western tip). For most commercial projects in ERCOT, the Connect and Manage process applies to systems under 10 MW.
Common rejection reasons:
- Incorrect TDU identified on interconnection application. Oncor, CenterPoint, AEP, and TNMP cover different geographic areas and have different requirements.
- PE stamp from out-of-state engineer who is not licensed in Texas
- Local amendments not addressed (some municipalities have adopted local NEC amendments that differ from the state default)
Notable consideration: Houston and Dallas-Fort Worth have high permit volumes. AHJ review times in those markets run longer than smaller municipalities. Plan for 4 to 8 weeks for building department review.
Florida
Governing codes: 2023 Florida Building Code (FBC), NEC 2020
PE stamp: Required for all commercial solar installations.
Structural requirements: 2023 FBC Risk Category 2 requires elevated wind speed design standards. Design wind speeds are 145 to 150 mph for most of the state. Miami-Dade and Broward counties require 170 to 180 mph design wind speeds due to High-Velocity Hurricane Zone (HVHZ) designation.
Miami-Dade and Broward specific: Products must be NOA (Notice of Acceptance) approved for the HVHZ. Module racking and attachment hardware must have Florida Product Approval numbers.
Interconnection:
- FPL: $400 interconnection fee; 30-day review target for commercial systems
- Duke Energy Florida: $240 fee; 20 to 30 business days
- TECO (Tampa Electric): $250 fee; similar timeline to Duke
Common rejection reasons:
- Wind speed assumptions not matching local wind zone requirements
- Miami-Dade/Broward: equipment without NOA or FPA numbers
- AFCI/GFCI requirements not addressed per 2023 FBC
Georgia
Governing codes: Georgia State Building Code (IBC-based), NEC 2020
PE stamp: Required for all commercial solar.
Interconnection: Georgia Power handles most commercial interconnections. The interconnection process for commercial systems typically runs 30 to 60 days for systems under 500 kW. Cooperatives (EMCs) operate independently.
Common rejection reasons:
- EMC interconnection documentation differing from Georgia Power requirements. A plan set built for Georgia Power may not satisfy the local cooperative.
North Carolina
Governing codes: North Carolina Building Code (IBC-based), NEC 2020
PE stamp: Required for all commercial solar.
Interconnection: Duke Energy Carolinas, Duke Energy Progress, and Dominion Energy each cover different territories with different interconnection requirements. North Carolina Uniform Interconnection Standards provide a baseline, but utility-specific supplements apply.
Common rejection reasons:
- Interconnection application not matching the correct utility's territory (the same county can be split between Duke EC and Duke EP)
- Structural calculations not matching local wind speed maps (coastal vs. inland differs significantly)
New Mexico
Governing codes: New Mexico Commercial Building Code (IBC-based), NEC 2017
PE stamp: Required for all commercial solar.
Interconnection: Public Service Company of New Mexico (PNM) is the primary utility. El Paso Electric covers the southern portion. Both have interconnection processes for commercial systems.
Jurisdictions Within States: Why State Rules Are Not Enough
The state building code sets the floor. Individual AHJs adopt local amendments that can be more restrictive. What the state code requires is the minimum. What a specific county or city requires may go beyond it.
Examples:
- Los Angeles County vs. the City of Los Angeles: Two separate building departments with similar but not identical requirements. A submittal prepared for the county may need revision for the city.
- Phoenix vs. Scottsdale vs. Tempe: All in Maricopa County, all APS service territory, but each municipality reviews permits under its own department with its own process.
- Pinal County, AZ: Growing commercial solar market with an active building department that has specific documentation preferences for large ground mounts.
For any project, the first step is identifying the exact AHJ, not just the state, and confirming the current requirements directly.
The Fastest Way to Confirm What Your Project Needs
Jolt Engineering has submitted commercial plan sets across key markets. If your project is in a state where we have experience, we can tell you what the AHJ requires, what the utility interconnection timeline typically looks like, and where the common rejection triggers are, before you submit.
Need a PE stamp for your project? Talk to us: joltengineering.com/commercial-solar-engineering
Founder & Principal of Jolt Engineering. 17+ years in commercial solar. Spent a decade on the EPC and client side before founding Jolt in 2017 to solve the problems he experienced firsthand.
