Collier County

A city address is usually permitted by the city, not the county — but not always, and some authorities keep building and hand electrical to someone else. Getting this wrong costs the whole submittal, because every requirement below belongs to whoever actually holds jurisdiction. Check the overlays in the same pass: an HOA, a historic district, a windstorm certification or a system-size cap can reshape the design, and all of them are cheaper to find now than after the array is laid out.

• Is this authority the AHJ for residential solar at this address? Yes 92% · adopting ordinance
• What does this authority permit itself, and what does it delegate? Both 90% · department page / permit checklist
• Is a permit required for a residential rooftop PV system? Yes 97% · department page / permit checklist
• Is there a separate electrical permit, or is it combined? Combined 85% · permit checklist
• Is a HOA or architectural approval required first? No 68% · published checklist (absence)
• Is there a historic-district review? No 55% · published checklist (absence) + secondary LDC reference
• Is a wind or windstorm certification required? No 62% · adopting ordinance
• Is a Specific Use Permit or Council approval ever required? Not required for a standard residential rooftop or accessory ground-mount PV system serving the dwelling; no SUP/Council-approval step appears in the County's PRSO submittal checklist. 55% · published checklist (absence)
• Is there a system-size cap on residential generation? The County's own permitting materials (ordinances, PRSO checklist, fee schedule) impose no distinct system-size cap of their own. In practice the effective cap comes from the utility's net-metering tiers: FPL Tier 1 is ≤10 kW AC, Tier 2 is >10-100 kW AC, Tier 3 is >100 kW-2 MW AC, each with different interconnection requirements. 58% · utility DG manual

Several authorities require the electrical permit to be pulled by a licensed electrician, or require the contractor to be registered with them BEFORE applying. Registration is not same-day. This is second on the list rather than fourth because it is the step most likely to stop the job before the drawings matter.

• Who is allowed to pull the electrical permit? Either 65% · permit checklist
• Must the contractor be registered with this authority before applying? Yes 80% · permit checklist
• Is a homeowner permitted to self-install and self-permit? Yes 82% · permit form

Almost everywhere wants a site plan, a one-line or three-line electrical diagram, equipment cut sheets with listings, and a structural attachment detail. Build it against the published checklist rather than the last jurisdiction you worked in — the checklist is what the reviewer marks against.

• What documents make up a complete submittal? For roof-mount PV: construction plans showing certification of component listing/spec sheets for all equipment, riser (one-line) diagram with wire sizes/types/junction boxes/combiners, fastening details, structural and wind load, and equipment location — plus 2 sets of plans. For ground-mount PV: the same plus a site plan (see Q10). 88% · published checklist
• How many copies, and in what format? 2 sets of plans for a residential ('Photovoltaic') permit, per the County's Building Review Performance Standard (Building Block A-126) exception table; submittal is otherwise made through the GMD electronic Public Portal (Electronic Plan Review). 68% · department bulletin
• Is a site plan required, and what must it show? Required only if ground-mounted. Must show a proposed site plan with property lines, setbacks, easements, water bodies, and all existing/proposed structures. If new impervious area exceeds 400 sq ft (and the survey is not older than 6 months), it must be signed and sealed by a Florida-licensed surveyor/mapper, architect, or engineer. If the property is on septic, the plan must show the proposed structure is at least 5 feet from the septic system per 62-6.005(2) F.A.C. No site plan is required for a roof-mounted system. 93% · published checklist
• Is a one-line / three-line diagram required? Yes 88% · published checklist
• Are string and conductor calculations required? Wire sizing is required to be shown on the riser diagram, but the County's published PRSO checklist does not separately itemize a 'string calculation' or voltage-drop calculation as its own submittal item. 55% · published checklist
• Is a structural PE stamp required, and at what threshold? No numeric threshold is published. The PRSO checklist requires 'Structural load and wind load' documentation and says plans must be 'signed and sealed' when applicable — in practice this is triggered whenever the attachment is not covered by a Florida Product Approval/NOA's prescriptive installation instructions (per Building Block A-137), rather than at a stated size/weight threshold. 60% · published checklist

Most authorities now take the whole application through a portal, and several states cap or constrain what a residential solar permit may cost. Check whether plan check is billed separately before you quote the job.

• Which permit portal does this authority use? GMCD Public Portal / CityView, at cvportal.collier.gov/cityviewweb (the County's Building Codes & Fees page notes the address recently changed from an older cvportal.colliercountyfl.gov / colliergov.net address). 92% · portal landing page
• Can the whole application be completed online? Yes 82% · department page
• What does a residential solar permit cost? $100.00 application fee per trade, plus $110.00 per inspection (photovoltaic permits). 95% · published fee schedule
• How is the fee calculated? Flat 88% · published fee schedule
• Is there a separate plan-check fee? No 72% · published fee schedule

Interconnection is a separate process from the permit and usually the longer pole. Where the utility does not depend on the permit being issued, running both at once is the single biggest saving available on a residential job.

• What is the stated plan-review turnaround? Statewide floor under FS 553.792(1)(a) (HB 803 / Ch. 2026-63, in force since 1 Jul 2026): 5 business days only if the electrical permit's declared value is under $15,000 for an existing single-family dwelling; otherwise 30 business days for a structure under 7,500 sq ft (which covers nearly all houses) — most residential PV jobs exceed $15,000, so the 30-business-day track normally applies. The County's own posted turnaround, Building Block A-126 ('Building Review Performance Standard,' last revised 2014), instead states a flat 5 business days for 'Single Family — new (One and Two Family Units)' alteration reviews and has not been updated to reflect the 2026 statutory split. 75% · enacted statute
• How long is an issued permit valid before it expires? FS 125.56(4)(d) (also from HB 803, in force since 1 Jul 2026) sets a floor: 'A building permit issued by a county for a single-family dwelling expires 1 year after the issuance of the permit or on the effective date of the next edition of the Florida Building Code, whichever is later.' The County's own Bulletin #16 ('Expired Permit Notice and Extension,' amended 6 Oct 2025 — i.e. before HB 803 took effect) instead still describes the older FBC 105.3.2 rule: work must receive an approved inspection at least every 180 days, and a permit not commenced within 6 months of issuance (or inactive 6 months) may lapse; extensions of up to 90 days are available for a fee of 10% of the original permit fee or $150, whichever is greater (capped at $750). 78% · department bulletin
• Which utility handles interconnection here? Florida Power & Light (FPL) for the great majority of the unincorporated County, Naples, and Marco Island. Lee County Electric Cooperative (LCEC) also serves part of Collier County — LCEC's own site describes a 'six-county service territory' that includes Collier, alongside Lee, Hendry, Charlotte, and Glades. 78% · utility territory page
• Where does the utility sit in the sequence? Parallel 78% · utility DG/net-metering guide

The NEC edition a jurisdiction enforces is often a cycle behind the newest one published, and local amendments sit on top of it. Rapid shutdown, conductor sizing and labelling all change between editions, so the edition in force is the first thing to establish, not the last.

• Which NEC edition is in force? 2020 95% · adopting ordinance / department page
• Which building code edition is in force? Florida Building Code, 8th Edition (2023), effective Dec. 31, 2023, adopted by Collier County Ordinance No. 2023-64 (amended by Ordinance 2024-40). 96% · adopting ordinance
• Which fire code edition is in force? Florida Fire Prevention Code, 8th Edition (2021) — Florida's version of NFPA 1 (2021) with statewide amendments. 88% · adopting ordinance / department page
• Are there local amendments to any of the above? Yes — Ordinance 2023-64 adds local permit exemptions (a Collier-specific list, e.g. minor repair/replacement items under $1,500 for owner-occupied single-family homes), incorporates local Wind Zone Maps, and amends FBC 107.3.1 (digital construction documents accepted on-site). Ordinance 2024-40 further amends FBC 110.3 (required inspections) and adds FBC 104.8/104.8.1 (liability/legal defense). Neither amendment is solar-specific. 92% · adopting ordinance
• What is the installation judged against? Florida Building Code, 8th Edition (2023) (with Collier's local amendments under Ordinances 2023-64 and 2024-40), NEC 2020 as adopted, and the Florida Fire Prevention Code 8th Edition (2021), plus the County's own Solar (PRSO) submittal requirements and Bulletin #4 inspection process. 88% · adopting ordinance

Ridge setbacks and roof access pathways are fire-service requirements and they constrain the array layout. They are the most common cause of a redesign after the fire department comments on a plan set.

• What ridge setback and access pathways are required? Governed by the Florida Fire Prevention Code, 8th Edition (2021) (Florida's amended NFPA 1), which nationally sets an 18-inch clear pathway/ridge setback on each side of a horizontal ridge for arrays up to 33% of plan-view roof area (36 inches above that, or 18 inches with NFPA 13D sprinklers), plus a minimum 36-inch-wide access pathway from eave to ridge. A Collier-specific fire-code amendment or bulletin restating this for PV was not located in this run. 50% · adopting code edition (inference)

Which rapid-shutdown rule applies follows directly from the NEC edition in force, and the initiation device has to be at a location the fire service can reach and identify. This is inspected, and it is labelled.

• Is rapid shutdown required, and to which NEC edition? Yes, to NEC 2020 (Article 690.12) — rapid shutdown for PV systems on buildings, since the County's adopted electrical code is currently the 2020 NEC. 85% · adopting ordinance (NEC edition)

The NEC sets a baseline for permanent markings at the service equipment and the disconnecting means. On top of that, an authority may specify its own wording, and the utility may specify more again. Where any of them writes its own text, a generic off-the-shelf label set will not pass — this is the detail most often fixed on a return visit.

• Which placards does this authority require at the service equipment? At minimum, all PV components/connections must be 'properly labeled' per the County's own inspection bulletin (checked at the 526-Solar Electrical Final inspection), which in practice means the full NEC 2020 Article 690/705 marking set (rapid-shutdown placard, PV disconnect/power-source directory, DC circuit labels, AC disconnect labels). The utility (FPL) separately requires its own labeling at the meter/disconnect and, for battery storage, a specific placard (see Q39/Q42). 78% · department bulletin
• Does the authority specify placard wording of its own? No 70% · department bulletin (absence of own wording)
• Does it specify letter height, colour or material? The County does not publish its own letter-height/colour/material spec beyond requiring labels to be 'properly labeled' per code (i.e., whatever NEC 2020 Article 690/705 requires). FPL's own standard for its labels is only 'permanent and weatherproof/UV resistant placard with engraved letters' — no specific height or colour given either. 65% · utility DG manual
• Is a site plan / facility map placard required, and what must it show? Not separately specified by the County beyond what NEC 2020 §690.56(B)/705.10 requires nationally: a permanent power-source directory/placard at the service equipment showing the location of each PV/other power-source disconnecting means, grouped with other on-site source placards. 55% · adopting code edition (inference)
• Does the UTILITY specify placards beyond the AHJ's? Yes — FPL requires its own additional labeling beyond code-minimum. For battery storage behind the meter, FPL's Electric Service Standards mandate: 'A placard must be permanently affixed to the meter enclosure stating "Battery storage utilized in this facility."' FPL also generally requires 'all labels must be permanent and weatherproof/UV resistant placard with engraved letters' for its Distributed Generation interconnections, and the customer is stated to be 'responsible for all labeling requirements.' 90% · utility DG manual
• Where must the labels be placed? At the service/meter equipment location generally (per NEC 690.56/705.10, readily visible, grouped with other power-source placards). FPL specifically requires labels on the meter socket/switch covers (and, for battery storage, a placard 'permanently affixed to the meter enclosure'). LCEC requires the customer's AC disconnect switch itself to be labeled/lockable and mounted separate from but adjacent to the meter socket per its Electric Service and Meter Requirements handbook. 78% · utility DG manual

Where the AC disconnect must sit relative to the meter is usually the utility's rule, not the building department's. Battery storage frequently carries its own permit, its own inspection and its own fire conditions.

• Where must the AC disconnect be, relative to the meter? Utility-dependent. FPL (Tier 2/3, >10 kW AC): the manual AC disconnect 'must be mounted separate from but adjacent to the FPL meter socket within 10 feet' and remain accessible to FPL. LCEC: the customer's manual disconnect switch 'shall be mounted within five feet and separately from the meter socket,' arranged per LCEC's Electric Service and Meter Requirements (ESMR) handbook. 85% · utility DG manual
• Must equipment be on a specific approved list? Yes 90% · department bulletin
• Are batteries permitted, and under what conditions? Yes — batteries are permitted as part of a PV system and are checked at the same final electrical inspection as the rest of the array (inverters, charge controllers, batteries, disconnects). FPL separately requires UL 1741-certified battery equipment and a placard on the meter enclosure for behind-the-meter battery storage; batteries integrated with a customer-owned renewable system may not export to the grid. 68% · department bulletin + utility DG manual
• Is there a separate ESS permit or inspection? No 72% · department bulletin
• Is a ground mount treated as a structure? Yes, effectively — a ground-mount PV array requires the same 'proposed site plan' the County requires of structures (property lines, setbacks, easements, water bodies, existing/proposed structures), and if it creates over 400 sq ft of new impervious area it must carry the same signed/sealed surveyor-or-engineer certification used for structures, plus the same septic-distance rule (5 ft) as a structure. 68% · published checklist (inference)
• Is a specific mounting system or attachment spacing required? No County-prescribed spacing figures were found; the County instead requires that mounting-bracket materials and attachment method match the 'approved submittals and engineering' for the specific installation, verified in the field at the '176 - Solar Tie Down' inspection (ground mount) and the '526 - Solar Electrical Final' inspection (roof mount). 72% · department bulletin

Booking is a portal, a phone call or an email depending on the authority, and the notice required is rarely zero. Book before the work is finished rather than after — the lead time, not the work, is usually what sets the date.

• How is an inspection booked? Portal 88% · department page
• How much notice is required? Effectively 1 business day — 'Scheduling for next day inspections can be done until 4:30 p.m. All inspections scheduled after 4:30 p.m. will be scheduled for the subsequent business day.' Time-specific (AM/PM) requests must be made by 1:00 p.m. the prior business day, but solar inspection codes are not on the time-specific-eligible list (see Q51). 90% · department page
• Are same-day or AM/PM windows offered? No dedicated AM/PM window for solar inspections. Time-specific (8:30 a.m.–2:30 p.m. slot) requests are offered only for a fixed list of concrete-pour-related codes (Footings, Pile Caps, Grade Beam, etc.) that does not include the solar codes (176-Solar Tie Down, 527-Electric Rough, 526-Solar Electrical Final). Instead, customers can opt for a proximity 'inspector is near your location' notification or a text-message alert. 88% · department page

Some authorities inspect their own solar work; some delegate it, and a few do not inspect the PV equipment itself at all. Who is coming determines what they will look at.

• Does this AHJ perform its own final solar inspection? Yes 95% · department bulletin
• If delegated, to whom? N/A — not delegated; the County performs its own final solar inspections in the unincorporated area (and, under interlocal agreement, in the City of Everglades). 88% · department bulletin

A rough-in or mid-roof inspection, where one is required, has to happen before the work it covers is closed up. Missing a stage means opening something back up, and it is the most expensive kind of correction.

• Which inspections are required, and in what order? Roof-mount: a single '526 - Solar Electrical Final' inspection scheduled the day the contractor energizes the system (plus a '503 - Service Change' if a service change is needed). Ground-mount, in order: '176 - Solar Tie Down' (mounting brackets, before panels are installed) → '100 - Footing' if concrete footers are poured → '527 - Electric Rough' (panels/wiring being installed) → '526 - Solar Electrical Final' (at energization), plus '503 - Service Change' if needed. Re-installation on an existing roof: a notarized Solar Panel Installation Affidavit is required on site at the '170 - Final Re-Roof' inspection. 95% · department bulletin
• Is a rough-in or mid-roof inspection required? Yes for ground-mount (176-Solar Tie Down and 527-Electric Rough are both mid-installation inspections); no separate rough-in/mid-roof inspection for roof-mount systems — Bulletin #4 describes only a single final inspection at energization for roof-top installs. 88% · department bulletin

The approved plan set, the permit, and the equipment listings should be on site and reachable. Inspectors routinely verify that installed equipment matches what was approved, and that the labels are the ones the plan set promised.

• Is there a published inspection checklist? Yes 90% · department bulletin
• What must be on site at inspection? A completed, notarized Solar Panel Installation Affidavit posted on site (verified at the 526-Solar Electrical Final inspection for new systems, and at the 170-Final Re-Roof inspection for re-installations on an existing roof), plus the approved permit plans. 88% · department bulletin / form
• Does the inspector verify labels and listings? Yes 95% · department bulletin

Passing gives you a final or an equivalent sign-off. That is not the same as permission to operate: PTO comes from the utility, and who tells the utility the inspection passed varies. A system left switched off for weeks is usually waiting on this handover.

• What is issued on pass? Final 68% · department bulletin (inference)
• Who notifies the utility for PTO? Installer 78% · utility DG/net-metering guide
• Is there a re-inspection fee? $110.00 per re-inspection 92% · published fee schedule
• How are corrections issued and cleared? Plan-review corrections/holds ('conditions') are cleared by uploading the corrected document to the relevant condition in the CityView Portal (the County's 'How to Resolve Conditions' page walks through this for several condition types); a failed field inspection is cleared by fixing the item and scheduling a re-inspection through the same Portal or the IVR phone system, at the $110 re-inspection fee. 65% · department page