Orange 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 — for any address in unincorporated Orange County. Incorporated cities (Irvine, Anaheim, Santa Ana, etc.) are separate AHJs and this record does not apply to them. 92% · adopting ordinance
• What does this authority permit itself, and what does it delegate? Both — building and electrical, permitted and inspected by the County Building Official. Fire code enforcement sits with OCFA, but OCFA sign-off is not required for residential PV ≤10 kW. 88% · adopting ordinance
• Is a permit required for a residential rooftop PV system? Yes. A solar permit is required. Routine operation, maintenance and like-kind replacement do not require a permit (OCCO 7-1-81(C)). 95% · published bulletin + ordinance
• Is there a separate electrical permit, or is it combined? Combined — the solar permit covers the PV installation. A separate electrical permit is required only where the service panel is upgraded; a separate plumbing permit only where a plumbing vent is relocated. 85% · published bulletin
• Is a Specific Use Permit or Council approval ever required? Yes, but only as a narrow discretionary exception. Under OCCO 7-1-81(F)(1) the Building Official 'may require an applicant to apply for a use permit if the official finds, based on substantial evidence, that the solar energy system could have a specific, adverse impact upon the public health and safety.' A use permit may be denied only on written findings, supported by substantive evidence, that there is a specific adverse impact and 'no feasible method to satisfactorily mitigate or avoid' it — and the findings must state why any feasible alternative was rejected. Both the requirement and the denial are appealable to the Hearing Officer (OCCO 7-1-23). No routine Board of Supervisors approval is involved. 90% · adopting ordinance
• Is there a system-size cap on residential generation? No cap on generation. 10 kW AC is the eligibility ceiling for the expedited/standard-plan route, not a limit on system size: 'Small residential rooftop solar energy system' is defined as ≤10 kW AC nameplate (or 30 kW thermal) on a single or duplex dwelling. Systems larger than 10 kW are permitted through the standard path with a 15-business-day review. The Standard Plan additionally caps its own use at a 225 A busbar, single-phase 120/240 V service, ≤2 inverters, load-side connection. 88% · adopting ordinance + bulletin

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 — the property owner, or an authorized agent (a licensed contractor, or any individual holding a notarized letter of designation from the owner). The SolarAPP+ instant-permit route is restricted to licensed contractors registered with SolarAPP+. 85% · department FAQ page
• Must the contractor be registered with this authority before applying? No — no County contractor registration is published as a precondition to applying. Registration is required with SolarAPP+ (NREL), not with the County, if the instant-permit route is used. 70% · department FAQ page + adopting ordinance
• Is a homeowner permitted to self-install and self-permit? Yes for the standard path — the property owner may obtain the permit directly. No for the SolarAPP+ instant route, which is 'Licensed contractors only (must register on SolarAPP+)'. 80% · department page + FAQ

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? Standard (non-SolarAPP+) path, per the Submittal Requirements Bulletin: (a) completed permit application form; (b) completed Eligibility Checklist for Expedited Solar PV Permitting; (c) a completed Solar Standard Plan (Central/String Inverter or Microinverter/ACM version); (d) a roof plan showing roof layout, PV panels, approximate roof access point, code-compliant access pathways, PV system fire classification, and the locations of all required labels and markings; (e) completed Structural Criteria with supporting documentation. The Standard Plan additionally requires manufacturer's specification sheets for the inverter, modules, combiner/junction boxes and racking, plus bonding/grounding installation instructions. Non-qualifying systems must add stamped structural drawings and calculations. SolarAPP+ path: SolarAPP+ approval number plus the County application in MyOCeServices. 88% · published checklist / bulletin
• How many copies, and in what format? Electronic. Ordinance 15-012 §(E)(2) requires the County to accept electronic submittal by email, County website or facsimile, and §(E)(3) requires an electronic signature to be accepted in lieu of a wet signature. In practice submittal is a document upload through the MyOCeServices portal. No paper copy count is published. 78% · adopting ordinance
• Is a site plan required, and what must it show? Yes — a roof plan is the required drawing. It must show: roof layout; the PV panels; approximate location of the roof access point; location of code-compliant access pathways; the PV system fire classification; and the locations of all required labels and markings. The Eligibility Checklist restates this as 'A diagram of the roof layout of all panels, modules, clear access pathways and approximate locations of electrical disconnecting means and roof access points'. The Structural Criteria separately requires a roof plan of the module and anchor layout. 90% · published bulletin + eligibility checklist
• Is a one-line / three-line diagram required? Yes — effectively. The County's Solar Standard Plan is itself a fill-in three-line/electrical schematic sheet with a conductor and conduit schedule, and completing it is a submittal requirement. Systems that cannot use the Standard Plan submit their own plans, which must show the equivalent. 75% · published standard plan
• Are string and conductor calculations required? Yes. The Solar Standard Plan requires inverter AC output ratings, DC and AC information, lowest-expected and average-high ambient temperature correction factors, conductor sizing via the conductor/conduit schedule, and 'Supplemental Calculation Sheets' plus 'Load Center Calculations' where a second inverter or a new load center is used. String limits are set by the Eligibility Checklist (max 4 strings per MPPT with inverter source-circuit fusing, max 2 without; max 1 non-inverter-integrated DC combiner per inverter; max 2 central inverters). 85% · published checklist + standard plan
• Is a structural PE stamp required, and at what threshold? Threshold-based, not size-based. If every item on the County's Structural Criteria checklist is answered YES, 'No additional calculations are required' and no stamp is needed. If ANY item is NO, the applicant must attach 'project-specific drawings and calculations stamped and signed by a California-licensed civil or structural engineer'. Key qualifying limits: single roof with no re-roof overlay; flush-mounted parallel to roof plane; 2"–10" gap under modules; no overhang of ridges/hips/gable ends/eaves; ≤4 psf for PV arrays; array covers ≤half of total roof area; anchor horizontal spacing within Table 1; mean roof height ≤40 ft; sheathing ≥7/16" OSB/plywood (1x skip sheathing acceptable). Ground-mounted and >10 kW systems fall outside this path. 90% · published structural criteria form

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? MyOCeServices (myoceservices.ocgov.com), a Salesforce-based Land Management System. For instant permits the County also uses SolarAPP+ (solarapp.nrel.gov) as the front end, with the resulting approval number entered into MyOCeServices under Private Property Permits → Solar Permits → SolarAPP+ Roof-mounted Solar. 92% · portal landing page + department page
• Can the whole application be completed online? Yes. Ordinance 15-012 §(E)(2) requires electronic submittal to be made available and §(E)(3) requires acceptance of an electronic signature in lieu of a wet signature. The Solar PV page describes the whole flow — apply, upload, pay permit fees and sign for issuance — inside MyOCeServices, and SolarAPP+ issues in real time. 90% · portal / department page + ordinance
• What does a residential solar permit cost? $455 — Roof-Mounted solar permit (includes County Standard Plan), FY 2026-27 rate. Ground Mounted $909. Commercial Solar $955. Energy Storage System (ESS) permit $353. Electrical permit (1–75 fixtures, includes panel upgrade to 400 A) $362 where a panel upgrade is part of the job. 90% · board-adopted fee schedule
• How is the fee calculated? Flat. 92% · board-adopted fee schedule
• Is there a separate plan-check fee? No — not for a standard residential rooftop system. The roof-mounted solar fee is a single flat fee that expressly '(includes County Standard Plan)'. The schedule's Electrical Plan Check line (20% of building permit fee) applies only to 'Residential more than 3000 sq ft or all Non-Residential projects as determined by the Building Official'. Recheck beyond three plan checks is a $475 T&M deposit; revisions to approved plans for solar are a $200 T&M deposit. 78% · board-adopted 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? Real time via SolarAPP+ (permit issued instantly on submission of the approval number). Otherwise, per the Submittal Bulletin: 3 business days where the Standard Plan, Structural Criteria and Eligibility Checklist are used and met; 5 business days for other applications; 15 business days for systems larger than 10 kW, ground-mounted systems, or systems on apartment-house or commercial roofs. Ordinance 15-012 §(F)(1) binds the 3-business-day figure as a legal obligation, not a target. 88% · published bulletin + adopting ordinance
• How long is an issued permit valid before it expires? Expires if work is not commenced within 12 months of issuance, and becomes null and void if work is suspended or abandoned for 180 days after commencement. One extension of up to 180 days may be granted by the Building Official on written request showing circumstances beyond the permittee's control; extension fee $175. A permit expired 180 days or more requires re-issuance with full plan check and permit fees. A permit also expires on change of ownership or change of contractor if work is incomplete. 90% · adopting ordinance + FAQ + fee schedule
• Which utility handles interconnection here? Address-dependent — this authority spans two utilities. Southern California Edison (SCE) serves most of unincorporated Orange County. San Diego Gas & Electric (SDG&E) serves southern Orange County, which includes major unincorporated communities such as Ladera Ranch, Coto de Caza and Las Flores. Confirm per address; do not assume SCE county-wide. 62% · utility company page
• Where does the utility sit in the sequence? Parallel, with a hard dependency at the end. The County's permit is independent of the utility and can be obtained first; OCCO 7-1-81(F)(5) states County approval 'does not authorize an applicant to connect ... to the local utility provider's electricity grid. The applicant is responsible for obtaining such approval or permission from the local utility provider.' The County's own electrical ordinance Sec. 90-18(a) adds that systems 'shall not be connected to the energy source until authorized by the Building Official.' On the SCE side, a signed final inspection from the AHJ is a required submittal before Permission to Operate is issued. So: interconnection application runs in parallel with permitting; PTO comes strictly after the County final. 85% · adopting ordinance + utility interconnection handbook

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? 2023 NEC — via the 2025 California Electrical Code, adopted and amended by County Ordinance No. 25-021 on 4 November 2025, effective 1 January 2026. (The 2025 CEC is Title 24 Part 3 and is based on NFPA 70-2023.) 88% · adopting ordinance / codes page
• Which building code edition is in force? 2025 California Building Code and 2025 California Residential Code (also 2025 Energy, Green Building Standards, Historical Building and Existing Building Codes), adopted and amended by County Ordinance No. 25-018 on 4 November 2025, effective 1 January 2026. Prior cycle was 2022, Ordinance 22-004, adopted 6 December 2022. 92% · adopting ordinance / codes page
• Which fire code edition is in force? 2025 California Fire Code, adopted and amended by County Ordinance No. 25-022 on 4 November 2025 (Orange County Codified Ordinances Title 3, Division 3, Article 1). Enforced by the Orange County Fire Authority as the fire authority having jurisdiction. 92% · adopting ordinance
• Are there local amendments to any of the above? Yes, local amendments exist — but NONE of them touch solar PV, energy storage, PV labelling or PV roof access. The Electrical Code amendments (Ord. 25-021, adding Sections 90-4 and 90-10 through 90-20) are purely administrative: enforcement, application to existing systems, underground utilities, conflicting provisions, alternate materials, powers of the Building Official, unsafe systems, permits, fees and plan review, inspection, hearing official, penalties. The Building Code ordinance (25-018) contains no solar or PV provision. The Fire Code ordinance (25-022) amends wildland fuel modification, spark arresters, open flames, sprinklers and high-piled storage — and adopts 'Chapter 12 Energy Systems ... in its entirety as amended by the SFM', i.e. with no County change to the solar PV or ESS fire provisions. 85% · adopting ordinances (three, read in full)
• What is the installation judged against? The 2025 California Electrical Code (2023 NEC base) as adopted by Ordinance 25-021, together with the 2025 CBC/CRC (Ord. 25-018) and 2025 CFC (Ord. 25-022) — all with administrative-only local amendments. The County's ordinance for solar additionally states that PV systems 'shall meet all applicable safety and performance standards established by the California Electrical Code, the Institute of Electrical and Electronics Engineers, and accredited testing laboratories such as Underwriters Laboratories and, where applicable, rules of the Public Utilities Commission regarding safety and reliability'. 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? The County publishes NO ridge-setback or pathway dimensions of its own. It requires the submitted roof plan to show 'approximate location of roof access point, location of code-compliant access pathways, PV system fire classification and the locations of all required labels and markings', and refers applicants to the State Fire Marshal Solar PV Installation Guideline for examples of clear-path access pathways. The Eligibility Checklist requires 'Clear access pathways provided' and 'Fire classification solar system is provided'. Dimensions therefore come straight from the adopted 2025 California Fire Code Chapter 12 / California Residential Code, which the County adopted in its entirety with no amendment. Note the CFC Chapter 12 solar pathway/setback section carries an exception for structures designed and constructed under the CRC — so for a one- or two-family dwelling the operative dimensions are the CRC's, not the CFC's. 72% · published bulletin + eligibility checklist + fire code ordinance

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 — rapid shutdown per CEC/NEC Article 690.12, at the 2023 NEC level, by virtue of the County's adoption of the 2025 California Electrical Code (Ord. 25-021, effective 1 Jan 2026) with no technical local amendment. 72% · adopting ordinance (inference from code 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? The County publishes a labelled markings diagram in its Solar Standard Plan showing the placards it expects at each component. As printed, these are: (1) 'WARNING: PHOTOVOLTAIC POWER SOURCE' — marked on junction/combiner boxes and on conduit every 10 ft; (2) 'DO NOT RELOCATE THIS OVERCURRENT DEVICE' at the backfed PV breaker (required where busbar is less than the sum of ampere ratings of all overcurrent devices supplying it); (3) 'WARNING — DUAL POWER SOURCES / SECOND SOURCE IS PHOTOVOLTAIC SYSTEM / RATED AC OUTPUT CURRENT ___ AMPS AC / NORMAL OPERATING VOLTAGE ___ VOLTS' at the service equipment; (4) 'PV SYSTEM AC DISCONNECT — RATED AC OUTPUT CURRENT ___ AMPS / AC NORMAL OPERATING VOLTAGE ___ VOLTS'; (5) 'WARNING — ELECTRIC SHOCK HAZARD. THE DC CONDUCTORS OF THIS PHOTOVOLTAIC SYSTEM ARE UNGROUNDED AND MAY BE ENERGIZED'; (6) 'WARNING — ELECTRIC SHOCK HAZARD. IF A GROUND FAULT IS INDICATED, NORMALLY GROUNDED CONDUCTORS MAY BE UNGROUNDED AND ENERGIZED' at the inverter (noted as normally already present on listed inverters); (7) 'WARNING — ELECTRIC SHOCK HAZARD. DO NOT TOUCH TERMINALS. TERMINALS ON BOTH LINE AND LOAD SIDES MAY BE ENERGIZED IN THE OPEN POSITION'; (8) 'PV SYSTEM DC DISCONNECT — RATED MAX POWER-POINT CURRENT ___ ADC / RATED MAX POWER-POINT VOLTAGE ___ VDC / SHORT CIRCUIT CURRENT ___ ADC / MAXIMUM SYSTEM VOLTAGE ___ VDC'; plus (9) a permanent plaque or directory denoting all electric power sources on or in the premises. CAUTION — THIS SHEET IS OUT OF CODE CYCLE: it cites CEC 690.5(C), 690.17, 690.35(F) and 705.12(D)(7) and CFC 605.11.1, all pre-2017 CEC / pre-2019 CFC numbering, while the County has adopted the 2025 CEC (2023 NEC). Several of those articles no longer exist and the required 2023 NEC labels (notably 690.12 rapid shutdown and the 705.10 power-source directory renumbering) do not appear on it. 80% · published standard plan
• Does the authority specify placard wording of its own? Yes — the County prints specific placard wording in its Solar Standard Plan (see q38). The wording is not County-original: it reproduces the model wording from the California Electrical Code, California Residential Code and California Fire Code, introduced by 'CEC Articles 690 and 705 and CRC Section R331 require the following labels or markings be installed at these components of the photovoltaic system'. So the County specifies wording, but it is adopting code wording rather than writing its own. 82% · published standard plan
• Does it specify letter height, colour or material? Yes — as guidance rather than mandate. The Standard Plan's informational note reads: 'ANSI Z535.4 provides guidelines for the design of safety signs and labels for application to products. A phenolic plaque with contrasting colors between the text and background would meet the intent of the code for permanency. No type size is specified, but 20 point (3/8") should be considered the minimum.' So: ANSI Z535.4 design, phenolic with contrasting text/background for permanency, and a 3/8" (20 pt) suggested minimum character height. No colour is mandated beyond 'contrasting'. 80% · published standard plan
• Is a site plan / facility map placard required, and what must it show? Two distinct things. (a) A permanent plaque or directory denoting all electric power sources on or in the premises is required at the service equipment — the Standard Plan states 'CEC 705.12 requires a permanent plaque or directory denoting all electric power sources on or in the premises' (this is 705.10 under the 2023 NEC now in force). (b) A roof-layout diagram must be SUBMITTED (not necessarily posted) showing all panels and modules, clear access pathways, approximate locations of electrical disconnecting means, roof access points, the PV system fire classification and 'the locations of all required labels and markings'. 75% · published standard plan + eligibility checklist
• Does the UTILITY specify placards beyond the AHJ's? Yes, in one specific case. SCE requires, where the customer's service equipment is modified to create or enlarge a customer section to accommodate a line-side tap, that 'Appropriate Placards must be installed labeling the sections': 'SOLAR INTERCONNECTION TERMINATION SECTION' and 'SCE UTILITY TERMINATION SECTION' — alongside an insulating red barrier and two separate barriers between the customer and SCE sections. SCE also requires the AC disconnect, where one is required, to be identified and locatable, with signage where it cannot be placed adjacent to the point of common coupling. No SDG&E equivalent was checked. 78% · utility interconnection handbook
• Where must the labels be placed? Per the County's Standard Plan markings diagram, placement is component-by-component: at the main service panel / point of interconnection (dual power sources plaque and the power-source directory); at the PV backfed overcurrent device ('do not relocate'); at the PV system AC disconnect; at the inverter (ground-fault warning); at the PV system DC disconnect (max power-point current/voltage, Isc, max system voltage); and marked on junction and combiner boxes and on conduit at intervals of every 10 ft ('WARNING: PHOTOVOLTAIC POWER SOURCE'). The submitted roof plan must additionally show the locations of all required labels and markings. 78% · published standard plan

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? For SCE territory: a single visible-open, lockable AC disconnect is REQUIRED only for agricultural/commercial/industrial, for residential where a non-self-contained utility meter is used, for all line-side taps, and for generation meter adapters / net generation output meters. A standard residential load-side retrofit on a self-contained meter therefore does not trigger the SCE requirement. Where one is required: for line-side connections 'the location of the single, fusible, visible open, lockable AC Disconnect shall be directly adjacent to the PCC'; where it cannot be adjacent, proper signage and accessibility are required and it should be in line of sight with approved signage. A plot plan is required whenever an AC disconnect is required, and must show the disconnect location relative to the SCE meter, whether meter and disconnect are within line of sight of each other, and dimensioned spacing between them. 'Lockable' means capable of being locked open with a 3/8" padlock. SCE's note: 'Customers should check with their local AHJ ... For safety reasons, SCE highly encourages customers to install an AC disconnect directly adjacent to their main service panel including installations in which it's not explicitly required by SCE.' The County itself publishes no AC-disconnect location rule. 76% · utility interconnection handbook
• Must equipment be on a specific approved list? No County-specific approved-equipment list. The requirement is listing and labelling under the adopted code: the Standard Plan states 'Listed and labeled equipment shall be installed and used in accordance with any instructions included in the listing or labeling (CEC 110.3). Equipment intended for use with PV system shall be identified and listed for the application (CEC 690.4(D)).' Ordinance 15-012 §(D)(3) adds that systems must meet standards of the CEC, IEEE and 'accredited testing laboratories such as Underwriters Laboratories'. 75% · published standard plan + adopting ordinance
• Are batteries permitted, and under what conditions? Permitted, but outside the expedited rooftop-PV path. The Eligibility Checklist for expedited permitting requires 'Solar system is utility interactive and without battery storage', and both County Standard Plans state they are 'not intended for ... systems that utilize storage batteries'. A battery system therefore takes its own permit (Energy Storage System permit, $353 FY 2026-27) and is judged against the 2025 California Fire Code Chapter 12 (Energy Systems), which the County adopted 'in its entirety as amended by the SFM' with no local amendment, plus the 2025 CRC. SolarAPP+ in this county is described as covering 'roof-mounted PV systems on existing residential homes' with no storage mentioned. 78% · published checklist + fee schedule + fire code ordinance
• Is there a separate ESS permit or inspection? Yes — a separate Energy Storage System (ESS) permit exists as its own line in the adopted fee schedule, $330 (FY 24-25) / $346 (FY 25-26) / $353 (FY 26-27), RA initial deposit $350. It is listed under Electrical Permits, separately from the Solar Permits block. 88% · board-adopted fee schedule
• Is a ground mount treated as a structure? Yes — handled as its own permitted structure, entirely outside the expedited rooftop path. Ground-mounted solar has its own fee line ($909 FY 26-27, roughly double roof-mounted), is excluded from the Eligibility Checklist ('The solar array is roof-mounted on one- or two-family dwelling or accessory structure'), is excluded from SolarAPP+ ('No ballasted or ground-mounted systems'), is outside the scope of both County Standard Plans and the Structural Criteria (which covers 'flush-mounted' arrays only), and carries a 15-business-day plan review rather than 3. 72% · published checklist + fee schedule + bulletin
• Is there a local rule on service upgrades or busbar sizing? No local code amendment on service upgrades or busbar sizing — the CEC governs unamended. There are two County-imposed *eligibility* limits, which are not code amendments: the Standard Plan and Eligibility Checklist may only be used where the PV system interconnects to a single-phase 120/240 V AC service panel with a busbar rating of 225 A or less, on the load side of the utility distribution equipment. A panel upgrade requires a separate electrical permit; the flat electrical permit fee covers 'Panel Upgrade up to 400 AMPS'. 82% · published checklist / standard plan + fee schedule
• Is a specific mounting system or attachment spacing required? No proprietary system is mandated, but the County publishes prescriptive attachment criteria that must be met to avoid an engineer's stamp (Structural Criteria form): array flush-mounted with module plane parallel to the roof plane; 2"–10" gap between underside of module and roof surface; no overhang of ridges, hips, gable ends or eaves; modules plus supports ≤4 psf (PV) or ≤5 psf (thermal); array covers ≤half of total roof area across all planes; single roof with no re-roof overlay; anchor horizontal (cross-slope) spacing not exceeding Table 1; staggered row-to-row anchors may double the spacing but never exceed 6'-0"; for manufactured plated wood trusses at flat to 6:12 the horizontal anchor spacing shall not exceed 4'-0" and adjacent rows must be staggered; anchor fasteners either 5/16" lag screws with 2.5" embedment into the rafter, or per the manufacturer's guidelines. Racking manufacturer's project-specific worksheets, tables or web-calculator results must be attached. 88% · published structural criteria form

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 — MyOCeServices (myoceservices.ocgov.com), Inspection Request. The adopted electrical ordinance also permits phone and written requests: 'Such request may be in writing, by telephone or by Internet, at the option of the Building Official.' General Building Inspection phone line (714) 667-8820. 88% · department page + adopting ordinance
• How much notice is required? 1 working day. 'The Building Official may require that every request for inspection be filed at least one working day before such inspection is desired.' 82% · adopting ordinance + department procedure manual

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 — the County performs its own inspection. 'Inspection Services Division provides professional building inspection, grading inspection, subdivision, and encroachment inspection services for the unincorporated areas of Orange County.' The adopted electrical ordinance Sec. 90-18(a) puts all permitted electrical systems 'subject to inspection by the Building Official', and Sec. 90-18(a) further bars connection to the energy source until the Building Official authorises it. No third-party or utility inspection substitution is offered. 92% · department page + adopting ordinance
• If delegated, to whom? Not delegated — N/A. (Fire code enforcement generally sits with Orange County Fire Authority, but the County's own bulletin states OCFA approval is not required for residential solar PV ≤10 kW, so no fire clearance is in the solar inspection path.) 85% · department page + 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? One consolidated inspection for expedited-eligible rooftop PV. Ordinance 15-012 §(F)(6): 'Only one inspection shall be required and performed by the building inspector for small residential rooftop solar energy systems eligible for expedited review.' §(F)(7): 'The inspection shall be done in a timely manner and should include consolidated inspections.' §(F)(8): if the system fails, a subsequent inspection is authorised but need not conform to the ordinance's requirements. Where the job includes a panel upgrade or an ESS, the associated electrical inspection applies on that permit; the County's permit-closure procedure checks that an electrical (420 or 455) inspection has occurred before releasing the permit for utility release. 85% · adopting ordinance
• Is a rough-in or mid-roof inspection required? No — for expedited-eligible rooftop PV, only one inspection is required, so there is no separate rough-in or mid-roof stage. 85% · adopting ordinance

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? No — the County publishes no solar inspection checklist. What it publishes is a pre-submittal Eligibility Checklist and Structural Criteria (both plan-review documents), plus two internal-facing documents: the 2020 Building Inspection Procedure Manual (staff desk procedures — conduct, communication, correction notices, permit closure) and LMS Inspection Steps (how staff build and complete a runsheet in Salesforce). Neither is an inspection checklist and neither contains a solar-specific list of items checked. 78% · department procedure manual + department pages
• What must be on site at inspection? The approved plans and the permit card (job card) must be on the jobsite. The County's inspection procedure directs that if the customer is not present and 'the approved plans and permit card are not on the jobsite', the inspector attempts to contact the contractor or homeowner and then leaves a 'Notice to Recall' inspection; conversely 'If no one is present but the approved plans and permit card are on the jobsite, complete the inspection if possible.' For SolarAPP+ permits the County additionally requires that the applicant 'must have both SolarAPP+ approved document and County documents on-site'. Access must be provided: 'It shall be the duty of the person requesting any inspection ... to provide access to and means for inspection of such work.' An adult of at least 18 must be present for the inspector to enter a residence. 85% · department procedure manual + department page + ordinance
• Does the inspector verify labels and listings? Yes — labels and listings are within scope. Both are made submittal-verifiable up front: the Eligibility Checklist requires 'All required markings and labels are provided' as a fire-safety item, the roof plan must show 'the locations of all required labels and markings', and the Standard Plan requires listed and labelled equipment per CEC 110.3 and 690.4(D). The County's inspection procedure directs the inspector to 'Check only those items specified by code and/or policy to be checked for each inspection' — labelling is specified by both the adopted code and County policy, so it falls inside that instruction. 62% · published checklist + department inspection procedure manual

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. The inspector signs the job card 'Approved'; at permit final the Supervisor reviews the inspection history, checks that all required inspections are complete and signed off, reviews all associated clearances (Building, Fire, Grading, OC Waste & Recycling), reviews the permit for utility release (checking that an electrical 420 or 455 inspection has occurred where an electrical service was installed), and then 'assign[s] a status of "Final" to the permit'. No certificate of occupancy or green tag is issued for a solar retrofit. 78% · department procedure manual
• Who notifies the utility for PTO? Installer/applicant. Ordinance 15-012 §(F)(5) places the duty squarely on the applicant: County approval 'does not authorize an applicant to connect ... to the local utility provider's electricity grid. The applicant is responsible for obtaining such approval or permission from the local utility provider.' On the SCE side, 'Signed Final Inspection from the local building and safety department or AHJ' is a required customer submittal, and SCE — not the AHJ — issues the Permission to Operate letter. 82% · adopting ordinance + utility interconnection handbook
• Is there a re-inspection fee? $198 (FY 2026-27; $184 FY 24-25, $195 FY 25-26). Charged 'for all inspection request services that require more than two inspection visits (Initial inspection and one correction visit). Additional inspection visits for the same correction that original notice of correction was issued, will require a re-inspection fee.' 90% · board-adopted fee schedule
• How are corrections issued and cleared? In writing, on a correction notice, and cleared by re-inspection. The inspector must 'Either sign the job card as "Approved" OR provide a written correction notice'; 'Do not give customers verbal approvals, corrections or OKs to continue work. All such instructions shall be in writing.' Correction notices carry a written disposition such as 'Correct & Proceed' or 'OK to wrap'; partial approvals are noted on the job card and in LMS. Correction notices are entered into LMS and are visible in the portal. Where a system fails inspection, Ordinance 15-012 §(F)(8) allows a subsequent inspection that need not meet the expedited requirements. For SolarAPP+ projects, a revision goes through SolarAPP+ first, then the revised document is uploaded to the MyOCeServices permit detail page for non-automated staff review with approval by email. 80% · department procedure manual + ordinance + department page