Seminole 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 — Seminole County Building Division is the AHJ for residential solar, but ONLY in the unincorporated area of the county. 90% · county guideline + department page
• What does this authority permit itself, and what does it delegate? Both — within its own scope (unincorporated county) Seminole County Building Division permits and inspects building AND electrical for residential PV itself (a PV submittal is reviewed on a structural track and an electrical track). It does not delegate permitting to any other agency; Planning/Zoning is a separate County division but is not a discretionary gate for ordinary rooftop PV (see q27). 75% · fee schedule + county guideline
• Is a permit required for a residential rooftop PV system? Yes — a building/electrical permit is required for residential rooftop PV in unincorporated Seminole County. 85% · county guideline
• Is there a separate electrical permit, or is it combined? Separate — Building and Electrical are charged and reviewed as separate permit fee lines (Fee Schedule Sec. 20.10 L(1)(b) 'Building Permit Fees for Structures Other than Buildings', which lists 'Solar panels' as an example, vs. L(4) 'Electrical Permit Fees'). The re-roof/solar notice separately states re-roof and solar are on separate permits from each other. 70% · fee schedule
• Is a HOA or architectural approval required first? No — an HOA/architectural-control approval CANNOT be required as a precondition, statewide, by force of Florida law. 85% · state statute (FS 163.04)
• Is there a historic-district review? No — unincorporated Seminole County has no historic-district overlay in its Land Development Code (its overlay list is Aquifer Recharge, Scenic Corridor, Lake Mary Blvd. Gateway Corridor, Econlockhatchee River Protection, Wekiva River Protection-Seminole Estates, Chuluota Nonresidential Design Standards, and SR 46 Scenic Corridor — no historic-preservation overlay named among them). Sanford's three National-Register historic districts (Commercial, Residential, Downtown) sit entirely within the City of Sanford, which is a separate, self-permitting AHJ (see jurisdiction.delegated_to) and outside the County's permitting scope. 60% · Land Development Code Part 10 (Overlay Districts) index
• Is a wind or windstorm certification required? Florida has no separate TDI-style 'windstorm certification' scheme; instead every roof-mounted PV system requires an engineer-sealed structural certification that the module/rack system meets a 139 mph ultimate design wind speed (V_ult) under FBC Sec. 1609.3, submitted as raised-seal (hard copy) or digitally-sealed (e-filed) engineering with structural detail, panel-layout sheets and hardware details. 85% · county guideline
• Is a Specific Use Permit or Council approval ever required? No — ordinary residential rooftop PV does not go to a Specific Use Permit or Board of County Commissioners hearing. No such process is named anywhere in the County's Building Division solar materials, and state law (FS 163.04) prohibits any local ordinance that 'prohibits or has the effect of prohibiting' solar installation, which forecloses a discretionary-hearing gate for a standard residential system. 58% · county forms/applications index (absence) + FS 163.04
• Is there a system-size cap on residential generation? No county-imposed cap on residential PV generating capacity was found. The only size-based structure in play is the STATE interconnection framework (Fla. Admin. Code R. 25-6.065), which sorts customer-owned renewable generation into Tier 1 (≤10 kW, minimal utility requirements, no insurance, disconnect switch usually exempt), Tier 2 (>10-100 kW) and Tier 3 (>100 kW-2 MW) — these are procedural utility tiers, not a legal ceiling on how large a residential system may be built. 55% · state administrative rule (25-6.065) + absence in county Building Division materials

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 — a licensed contractor pulls the permit online (the Building Permits Online workflow's Applicant step states 'Contractor will be the only selection available' for that path), or the property owner as owner-builder, who must visit the Building Division office in person with government ID before being allowed to use the online system. 80% · county ePlan/portal guide
• Must the contractor be registered with this authority before applying? Yes — a contractor's state license must be registered/current in the County's system (license, general liability certificate, workers' comp certificate or exemption, and a License Administration form) before an application can be submitted online. 80% · county ePlan/portal guide
• Is a homeowner permitted to self-install and self-permit? Yes — an owner-builder route exists. The property owner may act as their own contractor but must first visit the Building Division office in person with valid government-issued ID before using the online permitting system. 78% · county ePlan/portal guide

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? A complete submittal is: (1) FSEC System Approval Certificate for major components (modules + system design), OR an engineer's (Ch. 471 F.S.) certification containing the same data if not FSEC-listed (Ref. FS 377.705); (2) a one-line electrical diagram showing all major field-installed components, wire ID/sizing and grounding; (3) major component info (inverter, module, battery/charge-controller if used); (4) array info (layout, series/parallel string counts, total panel count, operating voltage/current, max system voltage, short-circuit current); (5) grounding details (equipment grounding conductor sizing, grounding electrode system); (6) array-mounting type (ground vs. roof); (7) for roof mounts, raised-seal (hard copy) or digitally-sealed engineering certifying the module/rack system meets 139 mph V_ult per FBC Sec. 1609.3, with structural detail, panel-layout sheets and hardware details, plus an engineer's certification that the building/roof can carry the added load without exceeding design live/dead loads. 90% · county guideline
• How many copies, and in what format? Electronic only. Applicant first requests an application number through 'Building Permits Online' (Click2GovBP), then uploads the full document set to the ePlan ProjectDox system within 10 calendar days of receiving that number. 80% · county ePlan/portal guide
• Is a one-line / three-line diagram required? Yes — 'One-line electrical diagram showing all major field installed electrical components, wire identification and sizing, and grounding' is a named required item. 90% · county guideline
• Are string and conductor calculations required? Yes — the guideline requires array/string data equivalent to string and conductor calculations: number of panels in series, number of parallel source circuits, total panel count, operating voltage (sum of series-string operating voltages), operating current (sum of parallel source-circuit currents), maximum system voltage, short-circuit current, plus equipment-grounding-conductor sizing. 88% · county guideline
• Is a structural PE stamp required, and at what threshold? Yes, for every roof-mounted system, with no small-system exemption stated: 'Raised seal engineering (if hard copy) or digital sealed (if e-Filed) certifying that the module and rack system will meet the 139 V-ULT in mph, as required by Section 1609.3 of the current Florida Building Code,' including structural detail, panel-layout sheets and hardware details, plus a certification that the building/roof can carry the added load without exceeding design live/dead loads. 88% · county guideline
• Is an electrical PE stamp required, and at what threshold? Not mandatory for a standard residential submittal. An electrical PE stamp only enters the picture as an alternate certification route: if the equipment is not FSEC-approved, 'Mandatory FSEC PV Certification is not required if the system is otherwise certified by an engineer licensed pursuant to Chapter 471, Florida Statutes' — i.e. the PE-stamp path substitutes for the FSEC listing, it is not an added requirement layered on top of it. 65% · county guideline

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? Two linked systems: 'Building Permits Online' (Click2GovBP, at https://semc-egov.aspgov.com/Click2GovBP/index.html) is used to request the application number and schedule/cancel inspections; 'ePlan' (ProjectDox) is used to upload the actual submittal documents and conduct plan review. 90% · county portal guides
• Can the whole application be completed online? Mostly yes for a registered contractor — application number request, document upload, plan review comments, fee payment and inspection scheduling are all online. The one required in-person step is for an owner-builder, who 'must visit the office with valid government issued identification prior to using our online system.' 82% · county ePlan/portal guide
• What does a residential solar permit cost? Roughly $75 base + ~$12 per $1,000 of job valuation, split across two permit lines: Building — 'Structures Other than Buildings' (base $30.00 + $6.00 per $1,000 valuation; 'Solar panels' is a named example) and Electrical — 'other' (non-new-construction) permit (base $45.00 + $6.00 per $1,000 of work value). E.g. a $20,000 job: ~$150 building + ~$165 electrical ≈ $315 total, before any card-payment or admin surcharges. 60% · fee schedule (Resolution 2024-R-139, filed 12/12/2023) — flagged stale by the County's own legislation page
• How is the fee calculated? Valuation — a small flat base fee plus a rate per $1,000 of construction/work value, on both the Building and Electrical lines (not a flat, per-kW or per-panel rate). 75% · fee schedule
• Is there a separate plan-check fee? No separate plan-check fee for a residential job — the fee schedule's only named 'Plan Review Fee' line is explicitly marked '(commercial only)', charging solely for a second-or-later resubmittal ($30/page, max $765); the initial review and first resubmittal are 'No Charge'. 65% · 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? Two statutory floors both apply and the shorter one governs based on job value, per FS 553.792 as amended by HB 803 (Ch. 2026-63), enrolled text, in force since 1 Jul 2026: 5 business days for an electrical/structural/accessory-structure permit application on an EXISTING single-family dwelling where the value of the work is under $15,000; 30 business days for the same categories on structures under 7,500 sq ft where the value is $15,000 or more (residential solar will usually fall in the 30-day tier once panels+inverter+labor are counted). The County's own 'New State Legislation Affecting Permits' page confirms it is implementing HB 803 as of the same effective date. 85% · enrolled state legislation (CS/CS/HB 803, 2026, amending FS 553.792)
• How long is an issued permit valid before it expires? One year from issuance, or the effective date of the next Florida Building Code edition, whichever is LATER (the FBC-cycle floor extends validity beyond a flat year if a new code edition is imminent). 88% · county department page quoting FS 125.56(4)(d) as amended by HB 803
• Which utility handles interconnection here? Duke Energy Florida. 85% · utility territory map (Duke Energy Florida)
• Where does the utility sit in the sequence? Effectively after permit / parallel-but-trailing: the County's permit and inspection process is independent of the utility, and Fla. Admin. Code R. 25-6.065 (the statewide investor-owned-utility interconnection rule that governs Duke Energy Florida) requires the customer to notify the utility at least 10 days before initially placing the generating equipment in service, with the utility completing any required physical inspection within 30 calendar days of receiving the signed Standard Interconnection Agreement. In practice the county final/electrical inspection and the Electrical Safety Inspection Affidavit (which must be on file before 'power [is] released to utility company') typically precede or accompany the utility's own sign-off for permission to operate. 65% · state administrative rule (25-6.065) + county affidavit form

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 — the Florida Building Code, Building, 8th Edition (2023) Chapter 27 (Electrical) adopts NFPA 70/NEC by reference, and the 8th-edition cycle is based on the 2020 NEC. 80% · ICC code index (2023 FBC, Building, 8th ed., Ch. 27) + county Appendix A Sec. 101.4.1
• Which building code edition is in force? Florida Building Code, 8th Edition (2023) — Building and Residential volumes, statewide, effective 1 Jan 2024, adopted for Seminole County via County Code Ch. 40 ('the Florida Building Code has been adopted and incorporated by reference'). 78% · adopting ordinance (Ch. 40) — snippet confirmed via search index; Municode itself 403s to automated fetch (JS shell)
• Which fire code edition is in force? Florida Fire Prevention Code, 8th Edition (2023) — the Florida-specific edition of NFPA 1 (2021 base edition), adopted statewide by the State Fire Marshal, effective 31 Dec 2023. 75% · State Fire Marshal page (statewide FFPC adoption) + county Appendix A generic reference
• Are there local amendments to any of the above? Yes — the County has an extensive local amendment set. Ord. 2021-18 (Chapter 40, Building and Construction, Appendix 'A') amends Chapter 1 (Administration) of the Florida Building Code county-wide, covering permit-application handling, alarm-system permitting, relocated-building wind-speed compliance, expiration/renewal, inspection procedures and more. No PV-specific local amendment was found within it — the only 'solar' hit in the full text is 'Solar Heat Gain Coefficient' (an energy-code glazing term, unrelated to permitting), confirmed against a positive control ('electrical' = 41 hits) and a fabricated control ('zzqqx' = 0 hits) run in the same document. 75% · adopting ordinance (Ord. 2021-18, Ch. 40 Appendix A)
• What is the installation judged against? The installation is judged against the Florida Building Code (8th ed., 2023 — Building/Residential volumes and Chapter 27 electrical incorporating NEC 2020), plus two statute-driven checks layered on top: FS 377.705 (FSEC Solar Equipment Standards, or PE-certified equivalent) for equipment listing, and FBC Sec. 1609.3 (139 mph V_ult wind design) for the structural/rack system. 80% · county guideline + adopted code citations

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 statewide Florida Building Code, Residential Sec. R324.6 (roof access for PV systems) rather than a Seminole-specific rule: two 36-inch-wide access pathways from eave/gutter to ridge on separate roof planes (one on the side facing the street or driveway where feasible), routed to avoid vent pipes/conduit/equipment obstructions, plus a ridge setback (36 inches clear on both sides of a horizontal ridge where the array covers more than 66% of the roof's plan-view area, with a smaller setback below that coverage threshold). 50% · code aggregator rendering of FBC-Residential R324.6 (primary FBC-R text not independently confirmed)

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, by force of the adopted electrical code — NEC 2020 Art. 690.12 rapid-shutdown requirements apply via FBC Ch. 27. The County adds no rapid-shutdown rule of its own; none of the Building Division's solar/PV documents (submittal guideline, re-roof-solar notice) mentions rapid shutdown by name. 62% · county guideline (absence) + NEC 2020 edition in force

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? The County requires no placard list of its own beyond deferring to the adopted electrical code. Under NEC 2020 (in force via FBC Ch. 27), the applicable placards at service equipment for a typical residential PV system are: a PV system disconnecting-means marking at each disconnect (690.13(B)/705.22); a plaque/directory identifying all electric power sources on the premises (705.10); DC-arc-flash / shock-hazard warning at ungrounded PV source/output circuit disconnects and combiner/junction boxes (690.31, 690.35); rapid-shutdown initiation-device labeling (690.56(C)); and conduit/raceway 'PHOTOVOLTAIC POWER SOURCE' marking at intervals (690.31(G)). 55% · absence in county documents + NEC 2020 (adopted by reference)
• Does the authority specify placard wording of its own? No — the County specifies no placard wording of its own for solar; the one-page solar submittal guideline contains no label text at all, and the re-roof-solar reinstallation notice likewise contains none, only a general instruction to meet 'current code' (FBC/NEC) and current product listings. 70% · county guideline + re-roof-solar notice (absence)
• Does it specify letter height, colour or material? Not specified by the County. Via the adopted NEC 2020: PV power-source conduit/raceway markings must be reflective, weather-resistant, and durable for the environment (690.31(G)); the rapid-shutdown label at the service disconnect must be a red background with white lettering, minimum height per 690.56(C)(4); general equipment markings under NEC 110.21(B) must be permanent and suitable for the environment. No county page adds a stricter or different colour/material/letter-height rule. 55% · absence in county documents + NEC 2020 (adopted by reference)
• Is a site plan / facility map placard required, and what must it show? Yes, via the adopted NEC rather than a County-specific rule: NEC 2020 Sec. 705.10 requires 'a plaque or directory...providing the location of the service disconnecting means and the photovoltaic system disconnecting means' wherever they are not co-located and visible from each other, posted at both the electrical service and the PV disconnect/inverter location. The County publishes no facility-map placard requirement of its own. 55% · absence in county documents + NEC 2020 705.10 (adopted by reference)
• Where must the labels be placed? County: no placement statement of its own found. Via the adopted NEC 2020: PV disconnect markings at each disconnecting means (690.13(B)); the 705.10 plaque/directory at BOTH the main electrical service and the inverter/PV disconnect if not co-located; DC shock-hazard/arc-flash warnings at ungrounded source/output circuit junction and combiner boxes; conduit/raceway 'PHOTOVOLTAIC POWER SOURCE' marking at intervals along exposed runs and at turns/penetrations (690.31(G)); rapid-shutdown label at the shutdown-initiation device (690.56(C)). 55% · absence in county documents + NEC 2020 (adopted by reference)

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? Governed by state rule, not a County rule: Fla. Admin. Code R. 25-6.065 provides that where an investor-owned utility (Duke Energy Florida here) requires a manual AC disconnect switch at all, it 'shall be mounted separate from, but adjacent to, the meter socket,' readily accessible to the utility and capable of being locked in the open position with a single utility padlock. Inverter-based Tier 1 systems (≤10 kW, the great majority of residential retrofits) are EXEMPT from the disconnect-switch requirement entirely unless the utility installs it at its own expense. 75% · state administrative rule (25-6.065)
• Must equipment be on a specific approved list? Yes — every PV module and inverter installed in Florida must either carry a Florida Solar Energy Center (FSEC) System Approval Certificate (listing approved major components) or be certified by a Ch. 471-licensed engineer to the same data set, per FS 377.705 (statewide statute establishing FSEC's solar-equipment-standards and testing authority). 85% · county guideline citing FS 377.705
• Are batteries permitted, and under what conditions? Batteries appear to be permitted as part of a PV submittal (the County's solar guideline includes 'Battery information (if used)' and 'Charge controller information (if used)' as optional major-component data fields), but no Seminole-specific document sets out siting, separation-distance or fire-code conditions for residential ESS. Those conditions would sit in the Florida Fire Prevention Code (NFPA 1, 8th ed. 2023), which incorporates NFPA 855 (Energy Storage Systems) requirements statewide. 50% · county guideline (battery field) + statewide FFPC/NFPA 855 adoption inferred
• Is a ground mount treated as a structure? Yes, functionally — solar panels (ground- or roof-mounted, when not part of new building construction) are fee-categorized by the County under 'Structures Other than Buildings' rather than as an accessory to the dwelling's own building permit, in both the general Building fee table and the separate Fire-Safety commercial-structures table, each of which lists 'Solar Panels'/'Solar panels' by name as an example. 72% · fee schedule (two line items)
• Is there a local rule on service upgrades or busbar sizing? No Seminole-specific local rule found on service upgrades or busbar sizing — I searched the County's Chapter 40 Appendix 'A' administrative amendments for 'busbar' and 'service upgrade' and got zero hits (against the same run's positive control 'electrical' = 41 hits, fabricated control 'zzqqx' = 0 hits), so installations are judged on this point against the adopted NEC 705.12 busbar/120%-rule provisions rather than any Seminole addition. 70% · adopting ordinance (Ord. 2021-18, Ch. 40 Appendix A) — absence proved with controls
• Is a specific mounting system or attachment spacing required? No specific rack brand, model or attachment-spacing table is prescribed by the County; instead the requirement is performance-based — an engineer-sealed certification (raised seal or digitally sealed) that 'the module and rack system will meet the 139 V-ULT in mph' design wind speed under FBC Sec. 1609.3, backed by structural detail, panel-layout sheets and hardware details, and a separate certification that the roof/building framing is not overloaded by the added dead/live load. 80% · county guideline

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 or Phone. Building/electrical inspections are requested through 'Building Permits Online' (Click2GovBP — select Application Number, then Schedule/Cancel Inspection, then the available Inspection Type). Fire inspections are booked online or by calling 407-665-7422 (leave a message with contact info). 85% · county inspection-scheduling guide + department contacts page
• How much notice is required? Requests must be submitted online by 11:30 p.m. the day before, to be scheduled for the next business day. 72% · department page
• Are same-day or AM/PM windows offered? No — the portal does not offer a real, honored AM/PM or same-day window. The scheduling confirmation screen itself states: 'the PM shown by the scheduled date is not applicable as the inspections are set by the inspector assigned to the inspection for that day.' 75% · county inspection-scheduling guide

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, by default — Seminole County Building Division performs its own building, electrical and (where triggered) fire final inspections through its own inspectors. The one exception is if the APPLICANT elects to use a state-licensed Private Provider under FS 553.791, in which case the private provider performs inspections/plan review, but the County Building Official still issues the permit and maintains the official inspection/permit record — the AHJ role itself is not delegated away. 80% · county Private Provider Requirements document
• If delegated, to whom? Only if the applicant affirmatively elects it: a state-licensed Private Provider (engineer/architect for plans review, or a licensed inspector under FS 468.603(5)(a) for inspections) registered with the County via PrivateProvider@SeminoleCountyFl.gov, per FS 553.791. This is an applicant choice, not a default County delegation. 75% · county Private Provider Requirements document

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? For a PV system reinstalled as part of a re-roof, the County's own notice lists the required inspection set and implies the same set applies to standalone PV: Re-roof — In-progress, Roof Final; Solar — Final Fire (if triggered), Final Electrical, Final Building — 'additional inspections may be required if deficiencies are found or if the system requires upgrades to meet current code.' 75% · county informational notice
• Is a rough-in or mid-roof inspection required? Not identified as a distinct requirement for a standalone PV permit — the County's solar-related inspection lists name only 'Final Fire, Final Electrical, Final Building' (see q54). A mid-roof/'In-progress' inspection is named only for the RE-ROOF permit itself, not for the PV system. 60% · county informational notice (absence in the named inspection list)

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 — the County publishes both a solar-specific submittal-requirements guideline (functions as the pre-inspection checklist) and a re-roof-solar informational notice that names the exact required inspection set for reinstalled PV. 78% · county guideline + informational notice
• What must be on site at inspection? A signed and notarized Electrical Safety Inspection Affidavit — from a licensed electrical contractor who personally inspected the system and attests it is 'in working condition, and safe to be energized' — must be on file before power is released to the utility company. Approved plans/permit documentation are the general on-site expectation for any County inspection (standard practice referenced across the County's process guides, though not spelled out as a single on-site checklist for solar specifically). 70% · county Electrical Safety Inspection Affidavit form
• Does the inspector verify labels and listings? Likely yes, as ordinary code-compliance practice, though not stated as a distinct County policy. NEC 110.3(B) (adopted statewide) requires equipment to be installed per its listing, and the re-roof-solar notice requires reinstalled equipment to meet 'all current product listings (UL, ETL, etc.)' as a condition the inspector is checking against at Final Electrical. 55% · county informational notice + NEC 110.3(B) (adopted)

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 — for an existing-home PV retrofit (the ordinary case), what is issued is passage of the Final Building/Final Electrical/Final Fire inspections plus the Electrical Safety Inspection Affidavit that permits power release, rather than a new Certificate of Occupancy (a CO applies to new construction/occupancy changes, not to an electrical/structural alteration of an already-occupied dwelling). 70% · county Electrical Safety Inspection Affidavit + re-roof-solar notice
• Who notifies the utility for PTO? Installer — in practice, the solar contractor/customer notifies Duke Energy Florida and executes the Standard Interconnection Agreement; Fla. Admin. Code R. 25-6.065 places the notice obligation on the CUSTOMER ('shall notify the investor-owned utility at least 10 days prior to initially placing customer equipment...in service'), and the County's own Electrical Safety Affidavit process (contractor sign-off before power release) sits upstream of that utility notification. 55% · state administrative rule (25-6.065)
• Is there a re-inspection fee? $50 for the first reinspection (all trades), $75 for the second, $100 for the third, $150 for the fourth and each subsequent reinspection. 70% · fee schedule — flagged stale by the County's own legislation page
• How are corrections issued and cleared? Not published as a distinct solar procedure. The general County process (from the Master Building/Engineering permit document) is: the reviewer issues comments/code-compliance items; the applicant must resolve and resubmit through ePlan as 'a response to comments' before the permit/inspection can proceed; a failed field inspection presumably triggers the tiered reinspection-fee schedule (q59) on reinspection request via the same online portal used to book the original inspection. 50% · county process document (general, not solar-specific)