Solar Permitting in a Shifting Policy Landscape: What to Know in 2026

Permitting a solar system in 2026 is not the same as it was in 2022. The code landscape has changed, utility interconnection rules have been updated, and state-level policy shifts have introduced new requirements that vary significantly by market. For solar installers operating across multiple states, the permitting environment is more complex than at any point in the industry’s history.

The installers who navigate this well are the ones who treat permitting knowledge as a competitive advantage rather than a back-office function. Here is a practical breakdown of what has changed and what your team needs to know. And if you want to hear these conversations in real time, events like Intersolar & Energy Storage North America (June 15-17, 2026, Rosemont, IL) bring together the engineers, policymakers, and utility representatives shaping these rules, and are worth attending for anyone serious about staying current.

The NEC Adoption Gap Is Wider Than Most Installers Realize

The National Electrical Code updates on a three-year cycle. The 2023 NEC is the current edition, but “current” does not mean universally adopted. As of 2026, NEC adoption varies significantly by state. Some states are on the 2023 edition. Others are still enforcing 2017 or 2020. A handful of states lag by two full code cycles.

For solar installers, this creates a specific problem: the correct plan set for a project in one state may be incorrect in another state with a different adopted edition. Rapid shutdown requirements under NEC 690.12, labeling requirements under 690.56, and interconnection rules under Article 705 all changed meaningfully between the 2017, 2020, and 2023 editions.

Submitting a plan set based on 2023 NEC to an AHJ still enforcing 2017 NEC creates corrections, even if the design itself is technically sound under the newer code. The reverse is also true: a plan set designed to the 2017 standard may not satisfy reviewers in jurisdictions that have adopted 2023 and expect updated rapid shutdown documentation and labeling.

What Changed in NEC 2023 for Solar PV

The 2023 NEC introduced updates to Article 690 that affect how plan sets are drawn and what documentation is required. Key changes include revised rapid shutdown initiation and response requirements, new equipment marking standards under 690.56, updates to arc fault circuit interrupter (AFCI) requirements for PV systems, and clarified ground fault protection rules for transformerless inverters.

Article 705, which governs interconnected power production systems, also saw updates that affect how utility interconnection is documented on the SLD and in the permit set. If your plan set templates were built on 2020 or earlier NEC, they may not satisfy reviewers in 2023-NEC jurisdictions without revision.

Our permit design team tracks code adoption by jurisdiction and draws every plan set to the adopted edition for each specific AHJ. This is not a manual check on each project. We maintain a live database of adoption status that is updated when states or municipalities change their adopted edition.

Federal Interconnection Rule Changes Are Reshaping Grid Access

Solar permitting is not just about the AHJ. Getting a solar system permitted means satisfying the local building department and getting it interconnected with the utility. In 2026, the utility side of that equation is more complex than it was three years ago.

FERC Order 2023, which revised the interconnection process for generation resources connecting to the grid, has created ripple effects even at the distribution level. While Order 2023 technically applies to wholesale transmission interconnection, its emphasis on queue reform and timeline transparency has influenced how utilities at the distribution level are managing interconnection applications for residential and commercial solar.

According to the Solar Energy Industries Association, interconnection delays remain one of the top barriers to solar deployment in several high-demand markets. For installers, this means that interconnection timelines are less predictable than they were, and projects that are permitted quickly may still wait on utility approval before they can go live.

The practical implication for installers: get the interconnection application in at the same time as the building permit, not after. Many utilities have their own documentation requirements that differ from what the AHJ requires. Having a plan set that satisfies both the AHJ and the utility documentation standard simultaneously reduces the total time from project start to energization.

State Policy Shifts Are Changing the Math on Solar

Several major solar markets have seen significant policy changes in the past two years that affect both the economics of solar and the permitting requirements associated with it. Net metering program changes in California (NEM 3.0), changes to interconnection procedures in Texas, and utility rate restructuring in several southeastern markets have all created new variables for installers.

These policy changes affect permitting indirectly but meaningfully. NEM 3.0 in California has shifted demand toward battery-paired systems, which carry additional permitting requirements for the battery components, the interconnection, and in some jurisdictions, fire code compliance for battery storage siting.

Installers expanding into new markets in 2026 need to understand not just the AHJ requirements for the building permit, but also the utility interconnection program rules, the applicable incentive structures, and any recent policy changes that affect how the system is designed or sited.

AHJ Requirements Continue to Drift

Beyond code adoption cycles, individual AHJs continue to develop their own supplemental requirements on top of the NEC. Some jurisdictions require specific plan set formats, particular calculation methods, or additional documentation that is not mandated by the adopted code edition.

AHJ-specific requirements are not published in a single location. They accumulate through plan checker feedback, pre-application meetings, and the institutional knowledge of engineers and permit expediters who submit regularly to each jurisdiction. For installers who submit to many different jurisdictions, tracking this information without a systematic approach is nearly impossible.

This is one of the reasons we built our AHJ database. Beyond tracking code adoption, we capture jurisdiction-specific preferences for plan set format, PE stamp requirements, and documentation standards. That database is the foundation of our permit design services, and it is updated continuously as our team encounters new requirements through active submissions.

What the Conversations at Intersolar Are About

Every year, Intersolar & Energy Storage North America brings together the companies, engineers, policymakers, and utilities that are actively shaping the solar industry. The June 2026 event in Rosemont, Illinois covers exactly the topics that affect permitting: state and federal policy updates, grid interconnection reform, utility-scale deployment challenges, and the regulatory shifts that cascade down to residential and commercial installations.

For permitting and engineering professionals, the value of these conversations is real-time intelligence. Policy changes at the state or federal level do not always come with clear implementation timelines or immediate AHJ guidance. Being in the room when these shifts are announced means you can start adapting before your competitors do.

NABCEP continuing education workshops at events like Intersolar also offer structured updates on code changes and professional standards. For engineers who maintain PE licensure and NABCEP certifications, these workshops count toward continuing education requirements while delivering practical content.

Whether or not you attend, tracking the conversations that come out of events like Intersolar, through session recordings, industry publications, and your engineering partners, keeps your team connected to the policy environment that is shaping permitting requirements in 2026 and beyond.

How to Stay Ahead of the Changes

The installers and engineering teams that manage the shifting permitting landscape best share a few common practices.

They track code adoption by state and update their plan set templates when jurisdictions change editions. They do not assume that what worked in one state will work in the next. They confirm AHJ requirements before drawing any plan set for a new jurisdiction.

They engage with the interconnection application process at the same time as the building permit, not sequentially. They understand that utility timelines are separate from AHJ timelines and that both need to be managed in parallel.

They invest in relationships with engineering partners who track these changes as a core part of their service. A plan set drawn by a team that is current on NEC adoption, utility requirements, and AHJ-specific formatting is a plan set that does not come back for corrections.

Our post on scaling solar installs efficiently covers how high-volume operations structure their workflows to manage permitting across multiple markets. For context on how plan sets and engineering stamps connect, see our post on permit drawings vs. engineering stamps.

Work with a Team That Tracks the Changes for You

Right Angle Engineering produces permit-ready plan sets for solar projects in all 50 states. Our team tracks NEC adoption, PE stamp requirements, AHJ-specific formatting preferences, and utility interconnection documentation standards so you do not have to.

When the policy environment shifts, we update our process before it becomes your problem. Contact us at Right Angle Engineering to learn how we can support your permitting workflow in any market.

Frequently Asked Questions

How do I find out which NEC edition my AHJ has adopted?

The most reliable source is the AHJ directly, either through their published fee schedule or pre-application process. State electrical boards also publish adopted code editions. The NFPA adoption tracker lists state-level adoption, but municipal adoption may differ from the state standard. Right Angle Engineering’s AHJ database tracks adoption at the jurisdiction level for all active markets.

What is the practical difference between NEC 2020 and NEC 2023 for solar PV?

The most significant practical differences are in rapid shutdown requirements under 690.12, labeling and marking requirements under 690.56, and AFCI requirements for PV systems. NEC 2023 also clarified several interconnection rules in Article 705. If your plan set templates were built on 2020 or earlier, review them against 2023 requirements before submitting to jurisdictions that have adopted the newer edition.

How does FERC Order 2023 affect residential solar installers?

FERC Order 2023 directly governs wholesale transmission interconnection, not residential distribution-level interconnection. However, its emphasis on queue reform and standardized timelines has influenced how utilities at the distribution level are modernizing their interconnection processes. The practical effect for residential installers varies by utility. Check with your specific utilities on any updates to their interconnection procedures.

Does battery storage add permitting complexity?

Yes. Battery storage systems carry additional permit requirements beyond the solar array. Depending on the jurisdiction, these include: building permits for battery enclosures, electrical permits for the battery system, fire code compliance documentation for battery storage siting, and utility notification or interconnection amendments. Many jurisdictions are still developing their battery permitting processes, so requirements vary more than they do for established solar installations.

What should I look for in an engineering partner to help manage policy changes?

Look for a team that actively tracks code adoption by jurisdiction and updates their plan sets when editions change. Ask whether they maintain a proprietary AHJ database. Confirm that they have licensed PEs in the states where you operate and that their engineers are current on NEC 2023 requirements. A partner who reacts to policy changes rather than anticipating them will cost you correction cycles when the environment shifts.