Santa Clara 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 the unincorporated area only 92% · department page (archived snapshot)
• What does this authority permit itself, and what does it delegate? Both — building and electrical, plus fire (County Fire Marshal's Office is in the same department). Plan check for eligible residential PV is delegated to SolarAPP+; inspection is never delegated. 85% · fee schedule + department page
• Is a permit required for a residential rooftop PV system? Yes 92% · department bulletin EL005, last revised 07/15/2025
• Is there a separate electrical permit, or is it combined? Combined — one Development (building) permit covers the PV electrical work 75% · fee schedule FY2026-2027, effective 1 July 2026
• Is a HOA or architectural approval required first? No — the County does not require HOA or architectural approval before issuing a PV permit 58% · department bulletin EL005 + SolarAPP+ eligibility list
• Is there a historic-district review? Possibly — the County's Permit Center page says a planning land-use application is required for 'any construction within a design review district, scenic road, historic district'. Whether rooftop PV triggers it is not addressed for solar specifically. 50% · department page (archived snapshot)
• Is a wind or windstorm certification required? No 62% · department bulletin EL005 + fee schedule
• Is a Specific Use Permit or Council approval ever required? Not for residential rooftop PV. Commercial solar facilities are a separate matter — in November 2010 the Board of Supervisors approved a Zoning Ordinance update specifically addressing Commercial Solar Systems. 62% · department page (archived snapshot)
• Is there a system-size cap on residential generation? No published kW cap on residential generation. The 15 kW figure in the fee schedule is a fee tier, not a limit. The streamlined route has practical ceilings: SolarAPP+ excludes electrical services larger than 400 A and individual batteries over 400 lb. For storage, CRC R328.5 as applied by the County caps individual ESS units at 20 kWh, with aggregate limits of 40 kWh in utility closets, basements and storage/utility spaces and 80 kWh in garages, detached accessory structures, on exterior walls, or outdoors on the ground. 65% · department bulletin EL004 + SolarAPP+ FAQ

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 — but route-dependent: SolarAPP+ requires a valid contractor's licence (owner/builder is explicitly excluded); a homeowner must instead use the conventional plan-check submittal 75% · department page — SolarAPP+ FAQ (archived snapshot)
• Must the contractor be registered with this authority before applying? No separate County contractor registration — but a Public Permit Portal (Accela) account must be created before a first application 60% · department page (archived snapshot)
• Is a homeowner permitted to self-install and self-permit? Yes, but not via SolarAPP+ — owner/builder projects are excluded from the instant-permit route and must go through conventional plan check 62% · department bulletin EL004, last revised 10/5/23

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? Conventional route (Bulletin EL005): single PDF containing — cover sheet (project address, scope of work, code data, project data); site plan showing all structures and electrical equipment; roof plan showing PV array location and required clearance to ridges and access pathways; electrical line diagram showing the whole electrical system with panel ratings, OCPD ratings, conductor and raceway types/sizes, make and model of all equipment, and a note citing the specific CEC interconnection method used (CEC 705.12(B)(2)(3)(a-e), 705.11 or 705.13); interconnection calculations supporting that method; data sheets for all equipment and rack systems; details of existing or new framing/support; structural details for rack attachment and spacing; a separate sheet showing all required labelling and signage; clear colour photos of the existing main service panel with dead front cover both in place and removed, plus a photo of the panel label to verify bus ratings; and where a listed PV hazard control system is proposed, tables of device counts plus the UL 3741 listing-report file information. SolarAPP+ route: the SolarAPP+ Approval Document uploaded to the Public Permit Portal replaces the plan set. 95% · department bulletin EL005
• How many copies, and in what format? One copy, electronic — 'Plans must be submitted as a single PDF file that includes all required documentation', minimum page size 11"x17". All supporting documents go inside that same PDF. 90% · department bulletin EL005
• Is a site plan required, and what must it show? Yes. Roof-mount: site plan must show the locations of all structures and electrical equipment. Ground mount adds: property lines and the distance from the array to them, the location of private sewage systems (septic tanks and fields), and elevation drawings giving minimum and maximum height above grade. 92% · department bulletin EL005
• Is a one-line / three-line diagram required? Yes — an electrical line diagram is a required sheet, and the bulletin's checklist lists 'Line diagram sheet provided' as a separate check item 95% · department bulletin EL005
• Are string and conductor calculations required? Yes — 'Interconnection calculations to support the referenced code method' are required, and the line diagram must carry conductor and raceway types and sizes, panel ratings and OCPD ratings 80% · department bulletin EL005
• Is a structural PE stamp required, and at what threshold? No PE stamp threshold is published for residential rooftop PV — Bulletin EL005 requires structural details for rack attachment and spacing and details of existing/new framing support, but names no engineer's stamp. For energy storage, Bulletin EL004 does set one: stamped and signed anchorage and/or attachment details from a licensed civil/structural engineer where equipment has an aggregate weight over 400 lb, or where equipment over 20 lb has its centre of mass 4 ft or more above the floor or grade. 72% · department bulletins EL005 and EL004
• Is an electrical PE stamp required, and at what threshold? Not required, and no threshold published. Bulletin EL004 accepts drawings 'signed by the architect or engineer(s), or by the contractor (electrical C-10) or by the owner who designed and will install the system'. 60% · department bulletin EL004

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, branded the 'Public Permit Portal' — https://aca-prod.accela.com/SCCGOV/. Two adjuncts: SolarAPP+ (NREL) performs the plan review and issues the Approval Document that is uploaded to the portal, and VuSpex GO is the County's mobile inspection-scheduling app. 88% · portal landing page / department page (archived snapshot)
• Can the whole application be completed online? Yes for eligible residential rooftop PV — register with SolarAPP+, submit the design there, then on the County's Public Permit Portal complete the Residential SolarAPP+ Permit application, upload the approval documents and pay; the permit issues automatically. Conventional-route applications are also accepted electronically, though an older County FAQ still says complex building applications may come over the counter. 88% · department page (archived snapshot)
• What does a residential solar permit cost? $450 base fee for a residential photovoltaic system up to 15 kW, plus $15 for each additional kW above 15 kW 95% · published fee schedule FY2026-2027
• How is the fee calculated? Tiered — flat base fee up to 15 kW, then per kW above that 92% · published fee schedule FY2026-2027
• Is there a separate plan-check fee? No — the residential PV line carries a single base fee with no separate plan-check line, and the 3% Information Technology fee is marked 'No' against the solar rows 78% · published fee schedule FY2026-2027

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? SolarAPP+ route: effectively zero — 'You will receive the permit automatically' once the SolarAPP+ approval is uploaded and the fee is paid. Conventional plan check: comments expected within 4 to 6 working weeks on first submittal, 2 working weeks on resubmittals and revisions; a Permit Technician verifies completeness within 72 business hours. 78% · department FAQ page (archived snapshot)
• How long is an issued permit valid before it expires? 12 months from the date of issue. Each approved or partially approved inspection automatically extends expiry by six months. If no inspection is approved within 12 months of issuance the permit expires and a new permit is needed; if none is approved for six months after an approved inspection, a 'Permit to Complete' is required. 90% · department page (archived snapshot)
• Which utility handles interconnection here? Pacific Gas & Electric (PG&E) — the interconnecting wires utility. Silicon Valley Clean Energy (SVCE) is the community-choice generation provider for the unincorporated county, but it does not handle interconnection; Silicon Valley Power and City of Palo Alto Utilities are municipal utilities confined to those incorporated cities and do not serve unincorporated territory. 75% · department page (archived snapshot)
• Where does the utility sit in the sequence? Parallel — the Rule 21 / NEM interconnection application is filed independently of the County permit and its Application Review and Engineering Review phases run alongside permitting. But PG&E's Final Inspection phase requires a 'Signed off Building Permit (finished project approved by local inspectors)', so Permission to Operate is gated on the County's final inspection. 82% · utility interconnection process document

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, Title 24 Part 3, effective 1 January 2026 82% · state code authority (California Building Standards Commission) + County building code page
• Which building code edition is in force? 2025 California Building Standards Code (Title 24) — California Building Code Part 2 and California Residential Code Part 2.5, effective 1 January 2026 82% · department page (archived snapshot) + state code authority
• Which fire code edition is in force? 2025 California Fire Code, Title 24 Part 9, effective 1 January 2026, administered locally by the County Fire Marshal's Office 68% · state code authority
• Are there local amendments to any of the above? Yes. Three named ones found: (a) County Ordinance No. NS-1000.136 amends CRC R328.4 to require energy storage systems to be installed outdoors or on the exterior side of exterior walls, not less than 3 ft from doors and windows directly entering the dwelling unit, and not below or above any emergency escape and rescue opening — with an elevation drawing required to prove it; (b) County amendments to the California Green Building Standards Code in Title C, Division C3, Chapter III of the County Ordinance Code, which remain in effect; (c) all-electric reach-code sections C3-62 to C3-63, which the County stopped enforcing on 30 July 2024, enforcing instead the 'electric-ready' requirements of California Energy Code §150.0(s)-(v). 85% · department page (archived snapshot) + bulletin EL004
• What is the installation judged against? The California Electrical Code (Title 24 Part 3, i.e. NEC as amended by California) articles 690 and 705, together with the CBC/CRC for structure and roofing and the California Fire Code for access and pathways. The County makes the interconnection method explicit: the line diagram must carry a note citing which method the system complies with — CEC 705.12(B)(2)(3)(a, b, c, d or e), CEC 705.11, or CEC 705.13 — and must be backed by interconnection calculations. Ground-mount DC conductors that are readily accessible must be guarded per CEC 690.31, by a minimum 5 ft fence with lockable gate or other approved means. 88% · department bulletin EL005

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 roof plan must show 'the location of the PV array and required clearance to ridges and access pathways', but the County publishes no current numbers of its own — the governing values are the California Residential Code / California Fire Code access-and-pathway provisions in force. The County's own published PV inspection checklist gives: 3 ft wide clear access pathway from eave to ridge on each roof slope with panels (hip roofs); two such 3 ft pathways on each slope for single-ridge roofs; panels no closer than 18 in. to a hip or valley where placed on both sides; panels no higher than 3 ft below the ridge for smoke ventilation; pathways at a structurally sound location able to carry firefighters. Applies to roofs steeper than 2:12. 55% · department inspection checklist (2014) + bulletin EL005 (2025)

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 NEC/CEC 690.12 of the edition in force (2025 CEC, based on 2023 NEC). The County recognises listed PV hazard control systems as the compliance route: where one is proposed, the submittal must include tables giving the number of devices (mid-circuit interrupters or similar) and the listing-agency file information from the UL 3741 report. 72% · department bulletin EL005 + NEC 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 publishes a dedicated signage table. Always required: 'CAUTION PHOTOVOLTAIC POWER SYSTEM CONNECTED' at the main service and at any panel with overcurrent devices supplying busbars fed from multiple sources (705.12(D)(4)); 'PHOTOVOLTAIC SYSTEM AC DISCONNECT' with rated AC output current and nominal AC operating voltage at the AC disconnecting means (690.54); 'PHOTOVOLTAIC SYSTEM DISCONNECT' at all PV disconnecting means including breakers and OCPDs used as PV disconnects (690.14(C)(2)); the DC disconnect rating plate giving rated maximum power point current and voltage, maximum system voltage, short-circuit current and charge-controller maximum rated output current (690.53); 'WARNING ELECTRIC SHOCK HAZARD — DO NOT TOUCH TERMINALS. TERMINALS ON BOTH THE LINE AND LOAD SIDES MAY BE ENERGIZED IN THE OPEN POSITION' at the DC disconnect (690.17); and the ground-fault warning at the inverter (690.5(C)). Conditional: the inverter-output-connection warning where OCPDs exceed 100% of bus rating (705.12(D)(7)); the permanent plaque/directory (690.56(B)/705.10). Battery systems add the 690.5(C) warning at the battery location and the 690.55 storage rating plate. Also specified for stand-alone systems (690.56(A)), single 120-volt systems (690.10(C)), and ungrounded systems (690.35(F)). Additionally, IFC/CRC marking 'WARNING: PHOTOVOLTAIC POWER SOURCE' on DC conduit, raceways, enclosures, junction and combiner boxes and disconnects. 70% · department signage requirements document
• Does the authority specify placard wording of its own? Yes — the County publishes verbatim placard wording of its own, sign by sign, in a dedicated signage-requirements document, and distinguishes 'signage shown in white and black' as instructional from 'signage in red and white' as the actual sign verbiage 78% · department signage requirements document
• Does it specify letter height, colour or material? Yes, all three. Material: 'SIGNS SHALL BE METAL OR PLASTIC, WEATHERPROOF AND SUITABLE FOR THE ENVIRONMENT THEY ARE INSTALLED'. Lettering: 'LETTERING SHALL BE ENGRAVED WITH A MINIMUM LETTER HEIGHT OF 3/8" PERMANENTLY AFFIXED'. Colour: warning markings are white letters on a red background, on reflective weather-resistant material; labels exposed to sunlight are to be phenolic. 75% · department signage requirements document + inspection checklist
• Is a site plan / facility map placard required, and what must it show? Yes — a permanent plaque or directory giving the location of the service disconnecting means and of the photovoltaic system disconnecting means (690.56(B) / 705.10). It must be applied 'at the exterior of building in readily visible location', and must also be at the location of the photovoltaic system disconnecting means. Required when the utility service disconnect and the PV system disconnect are not in the same location, and the County adds that 'Systems with micro inverters should have this signage.' Stand-alone systems get the 690.56(A) variant, which must additionally state that the structure contains a stand-alone electrical power system. PG&E separately requires a map showing the AC disconnect location whenever the disconnect is not grouped with the meter panel. 78% · department signage requirements document + PG&E Greenbook 060559
• Does the UTILITY specify placards beyond the AHJ's? Yes — PG&E imposes its own placards beyond the County's. Greenbook 060559 requires: permanently attached signage on the front of the disconnect explaining it is the AC disconnect switch for the generation, example wording 'UTILITY AC DISCONNECT SWITCH'; a UV and weatherproof label stating 'Utility Disconnect Switch' on the outside front of the switch; a visible ON/OFF label; a device label with ratings and UL certification. Labels 'shall be permanent and suitable for the environment and shall be engraved phenolic or comply with ANSI Z535.4. Lettering shall be a minimum 3/8" high and in all capitals.' Where the disconnect is not grouped with the meter panel, a map showing its location is required; if a Net Generation Output Meter is installed, proper labelling plus a location map where not grouped with the other meters. The County's own checklist also flags a common utility requirement: 'CAUTION! SUPPLY SIDE TAP. OPEN AND LOCK AC PV DISCONNECT BEFORE REMOVING METER' at the main service where a supply-side tap is used. 88% · utility DG manual (PG&E Greenbook 060559 Rev. 07)
• Where must the labels be placed? Per the County's signage table: at the main service and at any panel containing OCPDs supplying busbars fed from multiple sources; at the exterior of the building in a readily visible location (the plaque/directory) and also at the PV system disconnecting means; at the AC disconnect and/or point of interconnection, with the AC disconnect located adjacent to the inverter; at all PV disconnecting means including breakers and OCPDs used as PV disconnects; at the DC disconnect, which must be adjacent to the inverter; at the inverter (or near the ground-fault indicator if elsewhere); at the battery location where batteries are present; at each junction box, combiner box, disconnect and device where energized ungrounded circuits may be exposed during service; and on modules by the manufacturer. Conduit/raceway marking every 10 ft, within 1 ft of turns or bends, and within 1 ft above and below roof/ceiling, wall and barrier penetrations, plus marking adjacent to the main service disconnect clearly visible from where it is operated. PG&E's label goes on the outside front of the AC disconnect switch enclosure. 78% · department signage requirements document + inspection checklist

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? This is a PG&E requirement, not a County one. The disconnect must be installed between the PG&E meter and all generation sources, 'located 10 feet or less, in line of sight, from PG&E's electric meter at the point of common coupling or interconnection and is seen easily from the meter panel', easily accessible by PG&E on request, at the same grade level as the meter if installed outdoors with it, and mounted at a vertical height between 48 in. minimum and 75 in. maximum to the top of the enclosure. Not allowed on any floor or level above grade, on a roof, or in a room that is not an approved electric meter room. Must be lockable in the open position with a PG&E padlock taking a 5/16 in. shaft — keyed locks not allowed; must be manually operated, gang-operated, and give visible verification of the air gap; molded-case circuit breakers and pull-out disconnects are not acceptable. IMPORTANT EXEMPTION covering most residential jobs: an inverter-based system on a PG&E single-phase service up to 240 V may be exempted from installing a disconnect switch at all, as determined by PG&E, where the interconnected meter panel is self-contained (not transformer-rated), accepts form 'S' socket-based meters, is rated 320 A or less continuous, and is single-phase 120/240 V or 120/208 V. 92% · utility DG manual (PG&E Greenbook 060559 Rev. 07)
• Must equipment be on a specific approved list? No County-maintained approved list — compliance is by third-party listing. Modules listed to UL 1703 (AC modules to UL 1703 and UL 1741), inverters and charge controllers to UL 1741, energy storage systems to UL 9540 (cited by the County as CRC R327.2), PV hazard control systems to UL 3741 with the listing-agency file information supplied. PG&E separately maintains its own approved disconnect-switch list: models in the Eaton and Siemens Safety Switch Cross-Reference Guides up to 1200 A are pre-accepted. 75% · department bulletins EL004/EL005 + inspection checklist + PG&E Greenbook
• Are batteries permitted, and under what conditions? Yes, with a hard local siting rule. Under County Ordinance No. NS-1000.136 applying CRC R328.4, an ESS 'shall be installed... Outdoors or on the exterior side of exterior walls located not less than 3 feet from doors and windows directly entering the dwelling unit and not below or above any emergency escape and rescue openings', and a complete elevation drawing showing doors and windows on that wall must be submitted. All ESS must be listed to UL 9540. Individual units are capped at 20 kWh; aggregate 40 kWh in utility closets, basements and storage/utility spaces, 80 kWh in attached or detached garages and detached accessory structures, 80 kWh on exterior walls, 80 kWh outdoors on the ground — above which CFC 1206.1-1206.9 applies. Units must be separated from each other by at least 3 ft. Smoke alarms per CRC R314 are required in rooms and areas containing an ESS, with a listed heat detector where a smoke alarm cannot be used, audible at sleeping areas. Vehicle-impact protection (bollards to specified dimensions) is required where the ESS is in a driving path. Anchorage details stamped by a licensed civil/structural engineer are required over 400 lb aggregate, or over 20 lb with centre of mass 4 ft or more above floor or grade. 85% · department bulletin EL004
• Is there a separate ESS permit or inspection? No when the storage goes in with the PV — SolarAPP+ permits 'Residential roof-top PV solar systems and electrical service upgrades with Energy Storage' as a single permit with a single FI01 final inspection. Yes when the storage is standalone — 'Energy storage system projects that do not include a new PV solar system' are excluded from SolarAPP+ and need their own permit under Bulletin EL004. Batteries over 400 lb individually or in aggregate at their proposed location are also excluded from SolarAPP+. 80% · department page (archived snapshot) + bulletin EL004
• Is a ground mount treated as a structure? Yes. Bulletin EL005 gives ground mounts their own requirement set: structural details for the array structure; details for piers or other means of mounting the structure to the earth; locations of private sewage systems (septic fields); property lines and the distance from the array to them; elevation drawings giving minimum and maximum height above grade; and details for guarding readily accessible DC conductors per CEC 690.31 — a minimum 5 ft tall fence with lockable gate or other approved means. Ground mounts are also excluded from SolarAPP+ and must go through conventional plan check. 85% · department bulletin EL005
• Is there a local rule on service upgrades or busbar sizing? No County-specific busbar rule beyond the CEC, but there is a documented process rule: a residential PV project including an electrical service upgrade can be permitted through SolarAPP+ only if the service is 400 A or smaller — 'Projects with electrical services larger than 400A' are excluded. Bus sizing is policed at submittal: the bulletin requires clear colour photos of the main service panel with the dead front both on and off, plus a photo of the panel label 'to verify bus ratings', and interconnection calculations supporting the cited CEC 705.12 method. The County publishes a separate Electrical Service Change/Upgrade bulletin. 80% · department page + bulletin EL005
• Is a specific mounting system or attachment spacing required? No County-mandated mounting system or numeric attachment spacing. The submittal must carry data sheets for all proposed rack systems, details showing existing or new framing/support, and 'Structural details for rack attachment and spacing'; the inspection checklist requires modules attached to the mounting structure per the manufacturer's instructions and the approved plans, with roof penetrations flashed and counter-flashed. 78% · department bulletin EL005 + PV inspection checklist

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? Three ways: the VuSpex GO mobile inspection app (the County's recommended method, and the only one that can book multiple inspections at once); the Public Permit Portal (one inspection per request); or the inspection request phone line on (408) 299-5700. Fire Marshal's Office inspections for construction projects are booked separately on (408) 341-4420. 92% · department page (archived snapshot)
• How much notice is required? Next-day. 'The County provides next-day inspections for requests received before 3 p.m. on regular workdays.' Requests received on weekends or County-observed holidays are entered on the next regular workday and scheduled for the following workday or later. Inspections may be requested up to five days in advance. Cancellation before 8 a.m. on the day of inspection via the app or (408) 299-5700; after 8 a.m., by phone only. 92% · department page (archived snapshot)
• Are same-day or AM/PM windows offered? No published AM/PM windows and no same-day booking. The inspector calls the named contact on the morning of the inspection with a time window; app users receive the window by email and/or text once the inspector assigns a time. The contractor or a designated representative familiar with the project must be present. Some inspection types may be done virtually at the inspector's discretion — the published virtual-eligible list includes reroof progress and final, water heaters, underground electrical and re-inspection of minor correction items, but does not name PV. 85% · department page (archived snapshot)

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 — 'Inspections and approval by a County Building Inspector are required for all work being done with a permit' 92% · department page (archived snapshot)
• If delegated, to whom? Not delegated — the County of Santa Clara Department of Planning and Development, Building Inspection Division, performs the final solar inspection itself. The only thing delegated in this workflow is plan review, to SolarAPP+ (NREL), not inspection. 88% · department page (archived snapshot)

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 SolarAPP+ residential PV permit: one inspection, 'FI01 Project Complete', requested when installation is finished. Where a project carries multiple permits — original, revision (REV suffix), deferred submittal (DEF suffix, which the County names PV solar for new dwellings as an example of) — each permit must be requested separately, and an FI01 must be requested on every related record to close the project out. Conventional multi-trade projects follow the usual sequence (underground, rough, final) with each trade requested individually. Fire Marshal approval of a water source is required before a foundation inspection where combustibles will be on site. 78% · department page (archived snapshot)
• Is a rough-in or mid-roof inspection required? No for the SolarAPP+ rooftop route — a single FI01 Project Complete final is what the County describes. The general rule still applies though: 'Please do not cover ANY work until it has been approved by a County Building Inspector', so concealed work on a conventional-route job would need a rough inspection. 62% · department page (archived snapshot)

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 — two. The County publishes its own 'County of Santa Clara Inspection Checklist for Rooftop Photovoltaic (PV) Systems' (12 sections: array configuration, grounding, wire management, conductors, overcurrent protection, electrical connections, charge controllers, disconnects, inverters, batteries, signs and labels, fire safety), linked from its PV permits page. On the SolarAPP+ route, 'Print out a hard copy of the SolarAPP+ Approval Document and it will serve as an inspection checklist.' 88% · department inspection checklist
• What must be on site at inspection? Conventional route: hard copies of the approved plans, the permit card, any correction notices from previous inspections, and where required field reports from special inspectors, soils engineers and the engineer of record. The County is explicit that 'if you do not have the approved plans available when the inspector arrives they will not be able to conduct any inspections and you will need to reschedule.' SolarAPP+ route: a printed hard copy of the SolarAPP+ Approval Document (which doubles as the inspection checklist), plus a completed smoke detector and carbon monoxide alarm affidavit signed by the property owner — or the owner can instead let the inspector come inside to verify the alarms. A person familiar with the project must be present. 90% · department page (archived snapshot) + SolarAPP+ FAQ
• Does the inspector verify labels and listings? Yes. The County's published PV inspection checklist devotes a full section (Section 11: Signs and Labels) to verifying markings, and separately requires verification that modules are listed to UL 1703, inverters to UL 1741, charge controllers to UL 1741, and that module manufacturer, make, model and count match the approved plans. Bulletin EL004 requires ESS listed to UL 9540. On the SolarAPP+ route the printed SolarAPP+ Approval Document serves as the inspection checklist. 78% · department inspection checklist

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 FI01 'Project Complete' inspection is approved and the permit is finaled. No certificate of occupancy is involved for a solar permit. The County frames it as closing out the permit: 'To close out a permit and avoid costly delays and administrative fees you must request final inspections (FI01 Project Complete) inspections for all related records.' 70% · department page (archived snapshot)
• Who notifies the utility for PTO? Installer — the contractor submits the paperwork to PG&E, including the signed-off building permit. PG&E's Final Inspection phase requires 'Engineering approval, Net Energy Metering Agreement Form 79-978, Signed off Building Permit (finished project approved by local inspectors), Copy of Declarations Page of Home Owner Insurance'; PG&E then performs its own final inspection within 30 business days of a complete application where no system upgrades are needed, and Permission to Operate typically follows within about 3 business days of approval notification. The County does not notify PG&E. 85% · utility interconnection process document
• Is there a re-inspection fee? $79.36 building re-inspection fee 50% · fee schedule brochure, fees adopted 17 April 2018
• How are corrections issued and cleared? In the field: the inspector issues a correction notice, which must then be kept on site and produced at subsequent inspections; work must not be covered until approved; the applicant re-requests the inspection once corrections are made, and re-inspection of minor correction items (the County gives second ground rod and vacuum breakers as examples) may be done virtually. Where site conditions differ from the approved plans, the design professional must revise the plans and submit them to the County for approval before an inspection is called. In plan check: once review is complete an email goes to the applicant and their design consultants listing reviewer comments, and marked drawings and comment sheets can be downloaded from the portal; resubmittals are accepted through the portal but staff have three days to confirm the package is complete before target dates are assigned, and incomplete resubmittals are not reviewed. 72% · department page + FAQ (archived snapshots)