San Diego 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 parcels in the unincorporated area of San Diego County 95% · department page
• What does this authority permit itself, and what does it delegate? Both 90% · adopting ordinance
• Is a permit required for a residential rooftop PV system? Yes 96% · department page
• Is there a separate electrical permit, or is it combined? Combined 82% · online application guidance + fee schedule (PDS 613)
• Is a Specific Use Permit or Council approval ever required? Not for on-site residential rooftop PV — that is an accessory use requiring only a building permit. Off-site PV (energy exported to a different parcel) does need discretionary approval: under 10 acres requires an Administrative Permit (Zoning Ordinance Sec. 6952.b.1); 10 acres or more requires a Major Use Permit (Sec. 6952.b.2) plus a mandatory Major Project Pre-Application meeting. A Major Use Permit also changes the accessory-use status of a system. 90% · department page citing Zoning Ordinance
• Is there a system-size cap on residential generation? No cap on generation, but there is a threshold that matters: streamlined permitting applies to systems no larger than 38.4 kW AC nameplate (or 30 kW thermal) on a single- or two-family dwelling. Above that, the streamlined path is unavailable and the County notes large residential PV cannot be processed over the counter. 88% · adopting ordinance

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 CSLB-licensed contractor, or the homeowner as Owner-Builder 85% · County form
• Must the contractor be registered with this authority before applying? No — no prior registration with the County; the CSLB licence number is entered at the time of application 62% · online application guidance
• Is a homeowner permitted to self-install and self-permit? Yes 90% · County 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? Cover sheet; the County solar PV minimum construction specifications sheet (PDS 081s) reproduced on the plans; dimensioned roof plan; plot plan (only if not all equipment is on the main structure); single-line electrical diagram; electrical calculations; manufacturer's data and specification sheets for every piece of equipment (modules, inverters, batteries, racking); structural racking plan. 88% · published plan-check corrections list
• How many copies, and in what format? Online: one single PDF file uploaded to Accela. In person at PDS: two complete sets of legible plans and supporting documents. Revisions online are returned by email direct to the plan reviewer as an attached PDF. 85% · plan-check corrections list
• Is a site plan required, and what must it show? A plot plan is required only when some solar-related equipment — including the utility electric meter — is NOT on the main structure; it must then show the location of all structures and all solar-related equipment, per form PDS 090 (Minimum Plot Plan Information). A dimensioned roof plan is always required and must show all roof edges/ridges/valleys, all roof slopes, patio covers/trellises/decks/balconies, module layout, inverter/disconnect/panel/meter locations, routing of all conductors and conduit with materials identified, the stand-off distance of conduit above the roof, and grounding electrode type(s) and location(s). 88% · plan-check corrections list
• Is a one-line / three-line diagram required? Yes — a complete electrical single-line diagram 95% · plan-check corrections list
• Are string and conductor calculations required? Yes — electrical calculations for each string, circuit and array, including DC and AC conductor sizing per CEC Art. 690, ambient-temperature and conduit-fill correction factors, and number of modules per string 95% · plan-check corrections list
• Is a structural PE stamp required, and at what threshold? Conditional, no published numeric threshold. PDS 074 D.4 is a correction item reading 'This design requires plans and calculations prepared, stamped, and wet-signed by California-licensed civil engineer or architect' — issued case by case when the framing cannot be shown adequate. Ord. 10982 Sec. 91.1.107.1 separately empowers the building official to require a design professional. Standard roof mounts are otherwise carried by the racking manufacturer's allowable spans at 85 mph wind, Exposure C. 70% · plan-check corrections list + adopting ordinance

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? Accela Citizen Access — https://publicservices.sandiegocounty.gov/CitizenAccess/ (PDS section). NOT SolarAPP+. 92% · portal landing page + department pages
• Can the whole application be completed online? Yes — 'Residential roof-mounted solar PV permits, including combination solar PV permits with electrical service upgrade and/or advance energy storage systems, are available online' 92% · department page
• What does a residential solar permit cost? $292 permit fee — residential Photovoltaic Roof Mount applied for ONLINE. $345 if applied for in person. $502 for Photovoltaic Ground Mount. Plan review fee listed as N/A for all three. Re-inspection/progress inspection $205 if incurred. 85% · published fee schedule
• How is the fee calculated? Flat 90% · published fee schedule
• Is there a separate plan-check fee? No — plan review fee is listed as N/A for residential PV roof mount and ground mount 85% · 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? No published business-day figure. The County states residential on-site solar PV permits are 'typically processed over-the-counter (OTC)' — meaning they do not have to be submitted for plan review — but warns explicitly that 'OTC does not necessarily mean the permit will be issued the same day'. Large residential PV projects and all commercial PV cannot be processed OTC and must go to plan check. 78% · department page
• How long is an issued permit valid before it expires? Three years maximum from issuance. It expires earlier if work has not commenced within two years of issuance, or if work stops for 180 days at any point after commencing. 'Commenced' and 'not stopped' both mean the permittee has obtained an inspection verifying substantial progress — so a progress inspection must be called at least every 180 days. 95% · adopting ordinance
• Which utility handles interconnection here? San Diego Gas & Electric (SDG&E) — for effectively all of unincorporated San Diego County 80% · utility page
• Where does the utility sit in the sequence? Parallel — the SDG&E Rule 21 / NEM interconnection application runs alongside the County permit, but PTO comes last: SDG&E will not release the system until the AHJ's signed-off final inspection is provided. 62% · utility page (residential requirements page inaccessible)

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 96% · adopting ordinance
• Which building code edition is in force? 2025 California Building Code (with the 2024 IBC underneath) and 2025 California Residential Code (with the 2024 IRC underneath), both as amended by the County. Also 2025 California Plumbing (2024 UPC), Mechanical (2024 UMC), Energy and Green Building Standards codes. Adopted by Ordinance 10982, passed 4 March 2026, effective 30 days after passage. 96% · adopting ordinance
• Which fire code edition is in force? 2026 County of San Diego Consolidated Fire Code, 9th Edition — County amendments to the 2025 California Fire Code plus the ordinances of the 12 unincorporated San Diego County fire districts. Effective 2 April 2026. Alongside it, the 2026 County of San Diego Consolidated Wildland Urban Interface (WUI) Code. 96% · adopted fire code
• Are there local amendments to any of the above? Yes — extensively 96% · adopting ordinance
• What is the installation judged against? The County Electrical Code — 2023 NEC as amended into the 2025 California Electrical Code, plus County amendments (Title 9, Div. 3, Ord. 10982) — read together with form PDS 081s 'Solar PV Minimum Construction Specifications' (rev 02/19/2026), which the County requires to be reproduced on the submitted plans and which itself carries the note 'THESE ARE MINIMUM REQUIREMENTS AND SHALL NOT SUPERSEDE MORE RESTRICTIVE SPECIFICATIONS ON THE PLANS OR AS REQUIRED BY APPLICABLE CODE'. PDS 081s also binds the job to the Consolidated Fire Code and the WUI Code, latest versions. 92% · County minimum construction specification sheet

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? Pathways (R-3 and accessory to R-3): at least two 36-inch-wide pathways, each on a SEPARATE roof plane, with at least one on the street or driveway side; at least one 36-inch pathway on each roof plane carrying an array, or on an adjacent plane, or straddling both; pathways run from the lowest roof edge to the ridge and must be free of vent pipes, conduit and mechanical equipment. Ridge setback (smoke ventilation), measured clear on BOTH sides of the horizontal ridge: sprinklered building — 18 inches if array covers ≤66% of total roof area in plan view, 36 inches if more; unsprinklered building — 18 inches if ≤33%, 36 inches if more. Emergency escape: a 36-inch pathway from each required emergency escape and rescue opening, and modules must not be placed on the portion of roof below such an opening. Exceptions to pathways and ridge setback: roofs of 2:12 slope or less, and detached non-habitable accessory structures. Roof access points must not require ladders over doors or windows, must be at strong points of construction, and must not conflict with overhead obstructions such as tree limbs, wires or signs. 88% · plan-check corrections list + minimum construction specs

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. PV system circuits installed on or in buildings must include a rapid shutdown function controlling specific PV conductors per CEC 690.12(1) through (5), and must carry the placard 'PHOTOVOLTAIC SYSTEM EQUIPPED WITH RAPID SHUTDOWN'. Edition in force: 2023 NEC as adopted into the 2025 California Electrical Code, with County amendments. 92% · County minimum construction specification sheet

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? Six, from the County side: (1) DC conduit/raceway/enclosure/cable-assembly markings reading 'WARNING: PHOTOVOLTAIC POWER SOURCE'; (2) an alternate-power-source warning placard on the service disconnect identifying all pertinent equipment and disconnects with a site/building footprint; (3) the rapid shutdown placard 'PHOTOVOLTAIC SYSTEM EQUIPPED WITH RAPID SHUTDOWN'; (4) where approved plans show a de-rated main breaker, a placard at the panel; (5) fixed labelling of main service panel and busbar ratings, verifiable at time of inspection; (6) for ESS, nameplate and markings per CEC 706.4, and UL 9540 listing/labelling. On top of these SDG&E requires its own — see q42. 92% · County minimum construction specification sheet
• Does the authority specify placard wording of its own? Yes — three exact strings are specified by the County: 'WARNING: PHOTOVOLTAIC POWER SOURCE' (DC conduit/raceway markings); 'PHOTOVOLTAIC SYSTEM EQUIPPED WITH RAPID SHUTDOWN'; and, where the main breaker is de-rated, 'THIS PANEL HAS BEEN DE-RATED TO (insert amperage size). DO NOT INSTALL LARGER BREAKERS.' 95% · County minimum construction specification sheet
• Does it specify letter height, colour or material? DC conduit markings: minimum 3/8-inch-high WHITE lettering on a RED background. Alternate-power-source placard: metal or plastic, with ENGRAVED letters in a colour contrasting with the placard; attached by pop-rivets, machine screws or other approved fasteners; epoxy is expressly NOT an acceptable method of securing it. The County does not publish its own letter heights for the alternate-power placard — PDS 081s defers to 'the specifications of the San Diego Area Newsletter'. SDG&E's plaque sample supplies the heights in practice (see q42). 90% · County minimum construction specification sheet
• Is a site plan / facility map placard required, and what must it show? Yes. The alternate-power-source placard must show a footprint of the entire building and site, and mark the location of: the service point and utility meter, the AC and DC disconnects, the inverter, the PV array, and any generator or other generation source. It must also state the type of generation (PV array, stationary engine generator, wind turbine, batteries, fuel cell, etc.), and where batteries are present, their location (e.g. 'STORAGE BATTERIES IN GARAGE/ROOM 123'). 93% · County minimum construction specs + SDG&E plaque sheet
• Does the UTILITY specify placards beyond the AHJ's? Yes. SDG&E's NEM warning-plaques sheet specifies (a) the CAUTION plaque — heading 'CAUTION' at 3/4 inch minimum letter height, the line 'POWER TO THIS BUILDING IS ALSO SUPPLIED FROM THE FOLLOWING SOURCES WITH DISCONNECTS LOCATED AS SHOWN:' at 1/4 inch minimum, and the diagram callouts at 1/8 inch minimum; and (b) a SEPARATE plaque on the FACE of the utility AC disconnect reading 'PV SYSTEM DISCONNECT FOR UTILITY OPERATION' in 3/8-inch letters, with a plaque on EACH disconnect where multiple utility disconnects are installed. Both plaques: metal or plastic, engraved or machine-printed letters or electro-photo plating, contrasting colour, attached with pop-rivets or screws. SDG&E adds that the CAUTION plaque goes on the EXTERIOR of the service-disconnect enclosure, attachment must be made watertight and the enclosure rating maintained, and 'epoxy or other adhesive is no longer an acceptable method of securing'. Note that SDG&E's own text says fasteners must be 'acceptable to the AHJ'. 78% · utility placard specification sheet
• Where must the labels be placed? Alternate-power-source / CAUTION placard: attached to the service disconnect — SDG&E specifies the EXTERIOR of the service-disconnect enclosure. Utility disconnect plaque: on the face of the utility AC disconnect, one per disconnect. DC conduit markings: every 10 feet along interior and exterior DC conduit, raceway, enclosures and cable assemblies, AND within 1 foot of turns or bends, AND within 1 foot above and below penetrations of roof/ceiling assemblies, walls or barriers. De-rating placard: at the panel that was de-rated. Busbar/service-panel rating labels: fixed, and verifiable at the time of inspection. 92% · County minimum construction specs + SDG&E plaque sheet

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? County rules (these are the enforceable ones): AC and DC disconnects must be located WITHIN SIGHT OF THE INVERTER — this applies to remotely located inverters and to roof-mounted micro-inverters. The PV disconnect must additionally be at a readily accessible location OUTSIDE the building, or inside the building nearest the entrance of the PV system conductors. Integrated and micro-inverter systems require a ROOFTOP AC disconnect per CEC 690.14(D)(1) and (2). ESS disconnecting means shall be located outside, readily accessible, within sight of or within 10 feet of the ESS, lockable per 110.25. Utility side: SDG&E has not required a separate AC disconnect switch for inverter-based systems with a self-contained revenue meter (0–320 A socket-based, or 400 A K-based) since 1 January 2010 — but where one IS present its location must be given in the interconnection application and it carries its own plaque. 82% · County minimum construction specs (County half); secondary (utility half)
• Must equipment be on a specific approved list? No County-specific approved-products list, but listing by a nationally recognised testing agency is required and the standards are named: modules to UL 1703; inverters to UL 1741 and identified for use in interactive PV power systems (or provided as part of the UL 9540 listing); ESS listed and labelled to UL 9540, with UL 9540A referenced for battery/advanced energy storage; grounding devices listed to UL 2703 with the specific module named in the installation instructions; all proposed equipment listed or FIELD LABELED for PV application by an NRTL. Manufacturer's technical cut sheets must be submitted and must also be present on site. 85% · County minimum construction specs + plan-check list
• Are batteries permitted, and under what conditions? Permitted, and the County permits them online in combination with the PV permit. Conditions (CRC R327/R330 as adopted): system listed and labelled to UL 9540; installed per the manufacturer's listed instructions; NOT within the habitable space of a dwelling unit; installed per NFPA 70; inverters listed to UL 1741 or covered by the UL 9540 listing; grid-connected systems must use inverters listed for utility interaction; indoor installations of batteries producing hydrogen or other flammable gases during charging must be ventilated per the California Mechanical Code; systems in locations subject to vehicle damage must be protected by an approved barrier. Disconnecting means must be readily accessible, within sight of the ESS or within 10 feet of it, lockable per CEC 110.25 — and PDS 081s states the disconnecting means shall be located OUTSIDE; an integrated shut-down button satisfies 706.15 only if a separate outdoor disconnect is added where the unit is indoors. Vented storage cells need flame arresters (CEC 480.10(A)), sealed cells pressure-release vents (480.10(B)), cells in a lockable enclosure or room (110.27) with ventilation appropriate to the technology. Exceptions to the UL 9540 listing requirement: repurposed unlisted EV battery systems installed outdoors or in detached sheds at least 5 feet from exterior walls, property lines and public ways; battery systems integral to an electric vehicle complying with NFPA 70 625.48; and systems under 1 kWh. 88% · County minimum construction specs + plan-check list
• Is there a separate ESS permit or inspection? No — an ESS can be permitted on the same online record as the PV. The County's solar page offers 'combination solar PV permits with electrical service upgrade and/or advance energy storage systems' online. A separate permit is available but not required; PDS 081s notes that work such as re-roofing over previously permitted PV/BESS is 'required under separate permits'. 80% · department page
• Is a ground mount treated as a structure? Yes — treated as a structure and handled as a distinct project type. It requires a building permit with a plot plan meeting PDS 090 (Minimum Plot Plan Information), carries its own permit fee ($502 vs $292 online for roof mount), is the case where Environmental Health and/or Public Works review fees are 'typically' triggered, cannot be assumed OTC, and is subject to Zoning setbacks (handout PDS 276) and to Consolidated Fire Code Sec. 96.1.1205.5. Under that fire section a residential/agricultural ground mount generating primarily for on-site use is exempt from the fire-apparatus-access-road requirement subject to the fire code official's approval, and its fuel-modification zone may be reduced from 30 feet to 10 feet from the array and associated equipment, with combustible vegetation cut to no more than 6 inches. 90% · adopted fire code + fee schedule + department page
• Is there a local rule on service upgrades or busbar sizing? Yes, several. (a) Solar breaker + main breaker may not exceed 120% of the panel busbar rating; (b) panels with the main breaker at the CENTRE of the busbar may NOT use the 120% allowance — the combination may not exceed the busbar rating; (c) where the combined rating exceeds the busbar rating, the solar breaker must be at the end opposite the main; (d) main-breaker de-rating is allowed case by case only, requires electrical load calculations AND the panel manufacturer's authorisation, and requires a placard at the panel; (e) a line-side tap is typically NOT allowed on residential panels, the exception being 400 A or larger, and most side taps require third-party re-evaluation of the panel to UL standards; (f) a 400 A split-main panel with two 200 A breakers is expressly not treated as a true 400 A panel for sizing the solar breaker; (g) main service panel and busbar ratings must be verifiable at inspection by fixed labelling; (h) PV connection in a panelboard must be at the opposite (load) end from the input feeder or main. 85% · plan-check corrections list + minimum construction specs
• Is a specific mounting system or attachment spacing required? No named product or brand list. Requirements: all arrays attached to a racking system with positive connection to roof framing members (rafters, beams, pre-fab trusses). Plans must state size, embedment and spacing IN BOTH DIRECTIONS of the fasteners connecting racking to framing; the manufactured racking system's manufacturer and model; allowable span(s) of the racking considering 85 mph wind speed, Exposure C; the existing roofing material; and the spacing of existing roof framing. A dimensioned roof-framing plan is required, specifying all rafters, beams and headers and distinguishing new from existing. 85% · plan-check corrections list

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 — Accela Citizen Access, with a County help guide for scheduling inspections online; no ACA account registration is needed to look up a permit. Phone is the documented alternative: the Building Division on (858) 565-5920 during business hours, or a 24-hour inspection request hotline given as (800) 351-2551. 85% · County online help guide + department page
• How much notice is required? At least one working day's notice in most areas of the County; the County warns it may not be able to provide next-day inspections in some remote areas. 62% · department guidance document (dated 2013)

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. A County building inspector must approve each part of the construction, and all required inspections including the final must be passed. Ord. 10982 Sec. 91.1.104.4 gives the building official the alternative of accepting written inspection reports from approved agencies or individuals, but the default is County staff. For streamlined solar the ordinance describes 'consolidated streamline inspections' developed with concurrence from the County Fire Protection District. 88% · adopting ordinance + department guidance
• If delegated, to whom? Not delegated — the County inspects. The only named external hand is the fire side: the County Fire Protection District, which coordinates with the 12 unincorporated fire districts, concurs on the streamlined solar process. Manufactured/mobile home installations go to the California Department of Housing & Community Development instead of the County entirely. 80% · adopting ordinance

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? No solar-specific stage list is published. The general rule that governs: a County building inspector must approve each part of the subsequent construction; once construction begins an inspection must be requested and progress demonstrated every six months for the permit to stay active; all required inspections including the final must be passed before sign-off. For streamlined rooftop solar the ordinance refers to 'consolidated streamline inspections'. One sequencing rule IS solar-specific: above-ground conduit and wiring methods outside the building footprint must be approved by the building inspector BEFORE installation. 60% · County minimum construction specs + ordinance + dated guidance

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 published INSPECTION checklist specific to solar. What the County does publish, and what functions as the checklist in practice, is form PDS 074 (Residential Building Code Plan Check corrections list for roof-mounted PV and stationary storage battery systems, customer information version) and form PDS 081s (Solar PV Minimum Construction Specifications, rev 02/19/2026) — both are plan-check / construction-specification documents, and PDS 081s must be reproduced on the approved plans, which must be on site at inspection. 68% · absence proved against department pages and forms library
• What must be on site at inspection? The stamped, perforated approved set of plans; the Inspection Record Card (form PDS 291B) — both must be kept at the site and available to the inspector; all reference documents named on the plans, for grounding verification; the manufacturer's technical cut sheets for all equipment; a portable ladder complying with CAL-OSHA requirements, made available AND SECURED IN PLACE for the inspector; and, where the project includes a meter upgrade, rewire or panel relocation, the SDG&E Service Work Order. A re-inspection fee may be charged if the permit card is not properly posted or the approved plans are not readily available to the inspector. 90% · County minimum construction specs + plan-check list + guidance
• Does the inspector verify labels and listings? Yes. PDS 081s requires main service panel and busbar ratings to be 'verifiable at time of inspection with fixed labeling'; approved plans and all reference documents to be available on site for inspection verification of grounding; and manufacturer's technical cut sheets to be provided on site. Grounding devices must have manufacturer, model number and UL approval report number specified on the plans. So both labels and listings are verified at the site. 88% · County minimum construction specification sheet

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 — and there is no separate certificate. The County states plainly: 'A separate document will not be provided to signify Certificate of Occupancy. The completed, signed-off permit card is the Certificate of Occupancy and should be retained.' 80% · department guidance document (dated 2013)
• Who notifies the utility for PTO? Installer / applicant. The County does not notify SDG&E. The interconnection applicant submits the Rule 21 / NEM application to SDG&E, and SDG&E issues Permission to Operate after the AHJ's signed-off final inspection is provided to it. 60% · utility page + secondary installer guidance
• Is there a re-inspection fee? $205 — 'Re-Inspection/Progress Inspection Fee' 92% · published fee schedule
• How are corrections issued and cleared? Plan-check corrections are issued as written correction lists generated by County specialties (structural engineer, electrical/plumbing/mechanical, planner, and the County Fire Marshal where the site is not in a fire district), together with red/blue marks on the plans. The applicant corrects the plans, prepares a written response list saying where and how each item was addressed, and returns everything for re-check; the cycle repeats until cleared. For projects processed ONLINE the applicant responds directly by email to the plan reviewer with the revised plans attached as a PDF. Field corrections are cleared by re-inspection, which must be requested on a departmental form with the re-inspection fee paid — no further inspection is performed until that fee is paid. 78% · plan-check corrections list + department guidance