City of San Jose

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. The City of San Jose (Planning, Building & Code Enforcement Department, Building Division) is the AHJ for residential rooftop PV at addresses inside the city limits. Santa Clara County's building department has no role inside the incorporated city. 92% · fire department policy
• What does this authority permit itself, and what does it delegate? Both. The Building Division issues and inspects the building/structural and the electrical work for residential rooftop PV and for stationary storage batteries. Two things are NOT held by Building: (a) PV that is not on a rooftop (ground mount / carport) additionally needs a Planning Permit from the Planning Division; (b) PV/ESS on commercial or multifamily (3+ unit) property additionally needs Fire Department plan review (408-535-7750). Neither applies to a single-family/duplex/townhome rooftop system. 88% · building division bulletin
• Is a permit required for a residential rooftop PV system? Yes. 'A building permit is required before installing solar photovoltaic (PV) panels and/or energy storage batteries.' 95% · department page
• Is there a separate electrical permit, or is it combined? Combined in practice for a qualifying single-family rooftop system: 'Solar Photovoltaic System' is issued as one downloadable permit from SJPermits.org and 'You may secure multiple permits, if needed, with one application.' Single-family projects also get a single 'Combination' inspection request covering Building, Electrical and Plumbing/Mechanical. The fee schedule nonetheless carries a distinct electrical line item, 'Photovoltaic System (Single Family)', so the electrical component is separately priced even when applied for together. 72% · department page
• Is a HOA or architectural approval required first? No. The City does not require HOA or architectural approval before issuing a solar permit, and none of the required or 'if applicable' submittal items on the solar page is an HOA sign-off. The Design Considerations page notes only that a property in a Planned Development (PD) Zone 'must adhere to the architectural standards of the PD Zone and any HOA CCR rules' - a private obligation, not a City permit condition. Gov. Code 65850.5 independently bars conditioning approval on HOA approval. 65% · department page
• Is there a historic-district review? Yes, where the property is on the City's Historic Resources Inventory. 'If yes, your request for a building permit will include a review by a City planner. If appropriate to your project, you may need to get a Historic Preservation Permit.' Bulletin #282 and the solar page list 'Historic Preservation Permit, Adjustment, or Amendment' among the if-applicable submittals. The Historic Resources Inventory is checkable on a City ArcGIS map. 80% · department page
• Is a wind or windstorm certification required? No. There is no wind or windstorm certification requirement. California has no equivalent of Texas TDI windstorm certification, and San Jose's published design considerations for a solar project cover easements, flood zones, geologic and seismic hazard zones, grading, historic properties, PD zones, driveway/sidewalk work, tree removal, right-of-way use, WUI areas and zoning standards - wind is not among them. Wind loading is handled as ordinary structural design: 'Structural calculations verifying capacity of proposed systems to resist vertical and lateral loads.' 68% · department page
• Is a Specific Use Permit or Council approval ever required? Not for a rooftop residential system - it is an administrative building permit with no Council or hearing step. Two Planning-side approvals do exist: (a) 'PV projects not located on a rooftop require a Planning Permit' (ground mount, carport, canopy); (b) a Historic Preservation Permit, Adjustment or Amendment where the property is on the Historic Resources Inventory. Bulletin #265 adds that exterior roof- or wall-mounted equipment requires Planning approval regardless of weight unless it sits lower than an existing parapet or roof screen - which does not bite on a flush residential rooftop array. 72% · building division bulletin
• Is there a system-size cap on residential generation? No kW cap on residential generation is published. The published limits are technical, not capacity-based: PV system voltage must not exceed 600 volts for a one- or two-family dwelling; rooftop arrays qualifying for the online permit are capped by weight (under 5 lb/sq ft), point load (under 40 lb) and height (18 in above the roof surface) rather than by kW; and PV must comply with the development standards in Municipal Code Title 20. Storage is capped: max 20 kWh rating per ESS unit, 80 kWh aggregate in garages/detached accessory structures or outdoors, 40 kWh aggregate in enclosed utility closets, basements or storage/utility spaces. 62% · published checklist

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. Only a licensed contractor or the property owner of record may be the applicant for a permit downloaded online at SJPermits.org. Contractors may only pull permits matching their CSLB classification (for PV: C-10 Electrical, C-46 Solar, or B General). For plan-review projects the signer may also be an authorized agent or authorized tenant. 88% · department page
• Must the contractor be registered with this authority before applying? Yes. A contractor must hold a current City of San Jose Business Tax Certificate before pulling a permit, plus the State contractor's licence number and, if they have employees, workers' compensation coverage. No documents are submitted for the tax certificate; City staff verify status. 85% · department page
• Is a homeowner permitted to self-install and self-permit? Yes, as an owner-builder, though the City repeatedly advises against it. The owner must be the property owner of record per the County Assessor, submit an Owner-Builder Acknowledgement and Verification of Information form, and show ID at issuance. 82% · department page

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? Two paths. (A) QUALIFYING rooftop PV on single-family/duplex/townhome - no plan submittal at all: apply through the SJPermits.org Application Wizard, pay, download the Permit Card; the City Inspector reviews the electrical plan in the field on inspection day. Qualifying means rooftop, total panel weight incl. frame under 5 lb/sq ft, max concentrated load at each point of support under 40 lb, max height above roof surface 18 in, panels not ballasted. (B) NON-QUALIFYING (ballasted, heavier, taller, condominium, or non-rooftop) - Standard Plan Review Service: Building Permit Application + Smoke/CO Alarm requirements + Site Plan + Building Plans (framing plan, anchorage/interconnection/weatherproofing details, structural calculations per Bulletin #265, method of mechanical attachment for non-ballasted arrays) + Electrical Plans (system configuration and location of modules/array/equipment incl. Balance of System; conduit sizes and routing; location of disconnecting means; required overcurrent devices; short-circuit current and open-circuit voltage summary). If applicable: Geologic Hazard Clearance, Grading Permit, Historic Preservation Permit, Owner-Builder Acknowledgement, Tree Removal Permit, Construction & Demolition Diversion Deposit. 90% · published checklist
• How many copies, and in what format? No paper copies for the qualifying online path - nothing is submitted. For Standard Plan Review the submittal is electronic through SJePlans (single set, uploaded). For the smaller non-SJePlans services (Over-the-Counter, Residential Express) Bulletin #227 sets the format: PDF or PDF/A exported from the native file (not a scan) for most projects, text-searchable with OCR where scanned, layers flattened, unsecured security setting, landscape orientation, a 6x6 in stamp space on the cover sheet and a 3x3 in stamp space in each drawing sheet title block, separate PDF per sub-trade, calculations and cut sheets as separate files, bundled in a zip. 78% · building division bulletin
• Is a site plan required, and what must it show? Yes for the plan-review path. The site plan must show the building footprint, the location of the PV panels and/or storage battery equipment, and the locations of the photovoltaic and utility interconnection point. Easements must be shown if any exist. No site plan is submitted for a qualifying online rooftop permit. 88% · building division bulletin
• Is a one-line / three-line diagram required? Effectively yes for the plan-review path, though the City words it as content rather than as 'one-line diagram': the electrical plans must show system configuration and location of modules, array and equipment including Balance of System; conduit sizes and routing; location of disconnecting means; required overcurrent devices; and short-circuit current with a summary of open-circuit voltage - i.e. a single-line. No diagram is submitted for a qualifying online permit, but the inspector reviews the electrical plan on site. PG&E separately requires the AC disconnect to be 'clearly marked on the submitted single line diagram', and its interconnection portal generates an SLD. 70% · building division bulletin
• Are string and conductor calculations required? Yes. Structural calculations verifying capacity to resist vertical and lateral loads are required on the plan-review path. On the electrical side, site-specific calculations must be shown on plans and given to the field inspector: maximum PV source/output circuit voltage using a minimum temperature correction factor of 1.12 (a City of San Jose figure), max current and minimum circuit size with a 1.56 adjustment factor on module Isc, 125% of inverter max continuous output for conductor and OCPD sizing, conductor ampacity adjustment/correction factors, and conduit fill calculations when the field inspector asks. 85% · published checklist
• Is a structural PE stamp required, and at what threshold? No PE stamp for a qualifying rooftop residential system (no plans at all). For anything needing plans, the threshold is weight-driven under Bulletin #265: roof/floor-mounted equipment 201-400 lb needs plans and plan check but no professional design; OVER 400 lb roof-mounted (or over 200 lb suspended/wall-mounted) requires plans and calculations prepared by a licensed engineer or architect. Independently, B&P Code 5537 lets anyone prepare plans for a 1- or 2-storey wood-frame single-family dwelling, but the Building Official may deem any project to require a registered design professional, and anything deviating from conventional wood-frame construction must be stamped. 72% · building division bulletin
• Is an electrical PE stamp required, and at what threshold? None published for one- or two-family rooftop PV. San Jose does not require an electrical PE stamp on residential solar; for single-family projects the electrical review is done in the field by the assigned building inspector rather than in the office. Directive E-001 requires an office electrical plan review for PV only on multifamily or commercial/industrial projects, and for new or upgraded main services of 800 A and greater, but it stops short of demanding a PE stamp even there. 62% · building division directive

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? SJPermits.org for application, fee payment, permit download, inspection scheduling, inspection records and property/zoning lookup; SJePlans (reached from SJPermits) for electronic plan upload and plan-review correspondence on projects that need plan review. San Jose does NOT use SolarAPP+. 90% · portal landing page
• Can the whole application be completed online? Yes for a qualifying rooftop system: account registration, application through the Application Wizard, fee presentation, online payment and Permit Card download all happen in one SJPermits.org session, and inspections are booked in the same portal. For non-qualifying projects the whole application is still online - self-start at SJPermits, upload plans to SJePlans, receive and respond to plan-review comments there - but issuance waits on review and final fees. 86% · portal landing page
• What does a residential solar permit cost? No single published figure. San Jose does not print a flat solar permit price; the FY 2026-27 Building and Structure Permits Fee Schedule (effective 10 Aug 2026) builds it from parts. For a single-family rooftop PV permit pulled online the components are: Permit Issuance $211, reduced to 50% ($105.50) because Online Permits service is used; Electrical Permit for 'Photovoltaic System (Single Family)' at a 60-minute minimum inspection allocation charged at $315/hour = $315; plus a Record Retention Fee of 10% of permit cost ($20 minimum). That totals roughly $460 for a straightforward system. Any second alteration or an ESS on the same permit adds inspection time. 52% · fee schedule
• How is the fee calculated? Flat, in the sense of a fixed time allocation rather than project size: the fee is a fixed minimum inspection-time allocation (60 minutes for a single-family PV system, 120 minutes per additional unit) multiplied by the $315/hour inspection rate, plus a fixed permit issuance fee. It is NOT valuation-based, not per kW and not per panel. 68% · fee schedule
• Is there a separate plan-check fee? No for a qualifying rooftop system pulled online - there is no plan review, so no plan-check fee; the inspector reviews the electrical plan in the field. Yes for a non-qualifying system going through Standard Plan Review: plan review is billed at $325/hour (15-minute minimum over the counter, one-hour minimum for review intakes), with Expedited/Express/Special Handling Plan Review at 1.5x and a Plan Review Extension at $105. 76% · 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? Immediate for the qualifying online path - the permit is generated and downloaded during the SJPermits session, so there is no review queue. For a non-qualifying residential solar project going through Standard Plan Review, the closest published row is 'Alterations, no structural calculations': 10 working days first round, 5 working days for subsequent rounds, for architectural review; single-family mechanical, electrical and plumbing reviews are not queued at all because they are done in the field. 70% · department page
• Which utility handles interconnection here? Pacific Gas and Electric Company (PG&E). PG&E owns the distribution wires and the meter throughout San Jose and it - not San Jose Clean Energy - runs the interconnection process and issues Permission to Operate. San Jose Clean Energy (SJCE) is the City-run Community Choice Aggregator and is the default ELECTRICITY SUPPLIER (generation) for San Jose customers; it administers its own NEM/net-billing generation credit and true-up but has no interconnection role and cannot authorise a system to energise. 92% · utility DG manual
• Where does the utility sit in the sequence? Parallel, with a hard dependency at the end. The PG&E interconnection application (Agreement & Customer Authorization form, then the Standard NEM Interconnection Application) can and should be filed before or during the City permitting - PG&E advises submitting the single-line diagram 'as soon as possible, even before the system is built'. But Permission to Operate is not issued until PG&E holds evidence of the applicant's final electric inspection clearance from the AHJ. Under Rule 21 D.13.b, for NEM-1/NEM-2/NBT-1 facilities 1 MW or smaller, PTO is normally processed within 30 business days of PG&E receiving (1) a complete interconnection request, (2) a signed interconnection agreement and (3) that final inspection clearance; PG&E's own page says 5-10 business days typical, 30 maximum. Application fee $145 for NEM2 programmes at 1 MW or less. 88% · utility DG manual

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. The 2025 California Electrical Code (CCR Title 24 Part 3), based on the 2023 NEC, is adopted and applies to permit applications made on or after 1 January 2026. 90% · adopting ordinance
• Which building code edition is in force? 2025 California Building Code (CCR Title 24 Part 2) and 2025 California Residential Code (Part 2.5), effective for permit applications made on or after 1 January 2026. Also adopted: 2025 CMC, CPC, Energy Code, WUI Code, Historical Building Code, Existing Building Code and CALGreen. 92% · adopting ordinance
• Which fire code edition is in force? 2025 California Fire Code (CCR Title 24 Part 9), effective 1 January 2026. 86% · adopting ordinance
• Are there local amendments to any of the above? Yes. San Jose adopts the state codes with local amendments in Municipal Code Title 24, and the City states this in writing. The amendments that reach residential solar are: (1) a City of San Jose temperature correction factor of 1.12 to be applied to module Voc when calculating maximum PV source and output circuit voltage; (2) San Jose Fire Department roof access and pathway requirements applied alongside CRC R324/R329; (3) a San Jose Fire Department policy that residential ESS units must be separated by at least 3 ft and that standard UL 9540A thermal-runaway testing is NOT accepted as equivalent to large-scale fire testing, with all previously approved reduced-spacing master files suspended - SJFD instead recognises a 'unit' grouping only up to 20 kWh total; (4) the San Jose Reach Code (effective 08/01/2024) solar-readiness requirements. Note AB 130 (Stats. 2025, Ch. 22) bars NEW more-restrictive residential amendments from 1 Oct 2025 to 1 Jun 2031. 74% · adopting ordinance
• What is the installation judged against? The 2025 California Electrical Code (2023 NEC) Article 690 Parts I, III and IV plus Article 705, applied with San Jose's own additions, together with the 2025 CBC/CRC/CFC and San Jose Municipal Code Title 24. Bulletin #282 states: 'Unless supplemented or modified in Chapters 5 through 7 of the California Electrical Code, Chapters 1 through 4 shall apply to Solar PV and Energy Storage Systems.' The working document the inspector uses is the 2025 Residential Construction Guidelines, Solar Photovoltaic Systems section (pp. 236-242), which walks 690.7-690.9 sizing, 705.11-705.13 point of interconnection, environmentally durable labelling, 690.4(B)/690.11/690.41(B) arc-fault and ground-fault detection, 690.12 rapid shutdown, 690.13 disconnecting means, 690.31 wiring methods, 690.42 grounding, and roof access and pathways. 86% · building division bulletin

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? Ridge setback: minimum 18 in at the ridge where the array does not occupy more than 33% of total roof area; minimum 36 in where it occupies more than 33%. Exception: where sprinklers are installed, 18 in at the ridge is acceptable up to 66% of total roof area. Pathways: two pathways on separate roof planes from the lowest edge to the ridge, minimum 36 in wide, and one pathway on the street or driveway side, minimum 36 in. Arrays are not permitted on the portion of roof below an emergency escape and rescue opening, with 3 ft clearance required unless the PV is building-integrated. Roof access and pathways are not required for uninhabitable structures such as a detached garage or accessory structure. 85% · published checklist

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

• Is rapid shutdown required, and to which NEC edition? Yes - to the 2023 NEC as adopted in the 2025 California Electrical Code. NEC/CEC 690.12: 'Listed rapid shutdown devices installed at array boundary.' The service equipment must also indicate the location of the rapid shutdown initiation device and carry the associated label. 85% · published checklist

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

• Which placards does this authority require at the service equipment? At the service equipment: (1) a service equipment plaque bearing a site diagram that denotes each power source disconnect location, marked 'CAUTION: MULTIPLE SOURCES OF POWER'; (2) a label indicating the location of the rapid shutdown initiation device, with the standard rapid-shutdown graphic label; (3) where a load-side breaker-sum or 100%-option interconnection is used, a warning label at the breaker ('WARNING: POWER SOURCE OUTPUT CONNECTION - DO NOT RELOCATE THIS OVERCURRENT DEVICE' or 'WARNING: THIS EQUIPMENT FED BY MULTIPLE SOURCES...'). Elsewhere on the system: conduit containing DC circuits marked 'PHOTOVOLTAIC POWER SOURCE' or 'SOLAR PV DC CIRCUIT', and the PV system disconnect marked 'PV SYSTEM DISCONNECT' with 'WARNING ELECTRIC SHOCK HAZARD - TERMINALS ON THE LINE AND LOAD SIDES MAY BE ENERGIZED IN THE OPEN POSITION'. PG&E adds its own signage at the AC disconnect. 82% · published checklist
• Does the authority specify placard wording of its own? No. San Jose republishes the CEC/NEC wording verbatim rather than inventing its own text. Every placard string in the Residential Construction Guidelines - 'CAUTION: MULTIPLE SOURCES OF POWER', 'PHOTOVOLTAIC POWER SOURCE' / 'SOLAR PV DC CIRCUIT', 'PV SYSTEM DISCONNECT', 'WARNING ELECTRIC SHOCK HAZARD - TERMINALS ON THE LINE AND LOAD SIDES MAY BE ENERGIZED IN THE OPEN POSITION', and the two 705.12 breaker warnings - traces to Article 690/705. The useful local fact is that the City prints the required strings in one place, so the inspector is working from that list. 65% · published checklist
• Does it specify letter height, colour or material? Nothing solar-specific. San Jose specifies only that PV labelling and marking be 'environmentally durable' (the CEC 690.31/705.10 standard); it publishes no letter height, colour or material requirement of its own for solar placards. Contrast the same guidebook's dryer-duct rule, which does specify 'A durable placard, min 3" x 5"' - so the City does state dimensions when it wants to, and does not here. PG&E's AC disconnect signage requirements are separate and are set by PG&E, not the City. 58% · published checklist
• Is a site plan / facility map placard required, and what must it show? Yes, twice over. (1) City/CEC: 'Service equipment plaque with site diagram denoting each power source disconnect location' marked 'CAUTION: MULTIPLE SOURCES OF POWER' - i.e. the 705.10 facility-map plaque showing every power source disconnect. (2) PG&E: where the AC disconnect is more than 10 ft from the PG&E electric meter, a Site Map Placard must be installed; where more than one AC disconnect is installed, each must be labelled '1 of x, 2 of x'. If the disconnect is not adjacent to the point of common coupling, Rule 21 requires permanent signage at a PG&E-approved location giving a clear description of the device's location. 80% · utility DG manual
• Does the UTILITY specify placards beyond the AHJ's? Yes. PG&E requires, beyond anything the City asks for: the visible AC disconnect itself to carry markings or signage clearly indicating open and closed positions; a Site Map Placard where the AC disconnect is more than 10 ft from the PG&E electric meter; '1 of x / 2 of x' labels where more than one AC disconnect is installed; permanent signage at a PG&E-approved location describing the device's location where the disconnect is not adjacent to the point of common coupling; and, where the switch is not accessible outside locked premises, signage with contact information plus a PG&E-approved locking device. AC disconnect and signage are required on ALL non-inverter-based generators regardless of the decision tree. 80% · utility DG manual
• Where must the labels be placed? Service equipment / main service panel: the multiple-sources plaque with site diagram, and the rapid shutdown initiation device location label. At the interconnecting breaker: the 705.12 warning label for the option used. On conduit carrying DC circuits: 'PHOTOVOLTAIC POWER SOURCE' or 'SOLAR PV DC CIRCUIT'. At the PV system disconnect: 'PV SYSTEM DISCONNECT' plus the shock-hazard warning. At the AC disconnect (PG&E): open/closed position markings, and a Site Map Placard at the meter location when the disconnect is more than 10 ft from the PG&E meter. 76% · published 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? PG&E's rule, not the City's: install the AC disconnect within 10 ft of the PG&E electric meter. If the AC disconnect is more than 10 ft from the PG&E electric meter, a Site Map Placard must be installed. Where more than one AC disconnect is installed, label them '1 of x, 2 of x'. Whether a disconnect is required at all runs through PG&E's decision tree (line-side connection above the main breaker, three-phase at the service point, transformer-rated meter panel, meter panel rated over 320 A, meter types CL020/CL400/CL480/all K-based); a fusible AC disconnect within 10 ft is required on the line-side-connection branch. Rule 21 adds the qualitative requirements: near the point of interconnection, ganged manually-operated isolating switch, visible verification of separation, open/closed markings, reachable by PG&E personnel 24 hours a day without keys or special permission, and capable of being locked in the open position. Facilities with non-islanding inverters totalling 1 kVA or less are exempt. 78% · utility DG manual
• Must equipment be on a specific approved list? Yes, effectively. Bulletin #282: 'Installed equipment is required to be listed and labeled according to applicable UL standards. Installers must provide evidence that equipment is appropriately listed/labeled and meets the code required UL standards at the time of inspection.' ESS must be listed and labelled to UL 9540 (or be sited at least 5 ft from exterior walls, public ways and property lines) and the spacing/configuration/capacity of any multi-unit grouping must be demonstrated in the UL 9540 listing and UL 9540A testing. PG&E separately requires equipment to appear on the GoSolarCalifornia approved equipment list, or an NRTL document demonstrating UL 1741 certification for inverters not on it. The City also publishes a bulletin on 'Approval of Non-Listed Electrical Equipment' for the exception route. 76% · building division bulletin
• Are batteries permitted, and under what conditions? Yes, under detailed conditions. A building permit is required. Batteries qualify for the online SJPermits path only if they use a City-approved anchorage detail from Bulletin #282 or an approved SSB Masterfile on file with the Building Division; the online permit table marks Stationary Storage Battery System as 'Limited' for single-family. Substantive conditions: listed and labelled to UL 9540 (or sited at least 5 ft from exterior walls, public ways and property lines); maximum 20 kWh rating each; minimum 3 ft spacing between units unless large-scale fire testing accepted by SJFD justifies less; aggregate 80 kWh in garages and detached accessory structures or outdoors on the exterior side of an exterior wall (min 3 ft to doors and windows unless the UL 9540 listing permits less); aggregate 40 kWh maximum in enclosed utility closets, basements or storage/utility spaces, which must be finished in noncombustible material or minimum 5/8-in Type X gypsum board, with garage-to-house separation at openings and a smoke alarm (or listed heat detector interconnected with the smoke alarms where the listing prohibits a smoke alarm); mechanical ventilation per the CMC for indoor installations producing flammable gases; ESS releasing toxic gas prohibited for residential use; impact protection where installed on garage back walls or within 36 in of the vehicle driving path, and on side walls within 24 in of the back wall and 36 in of the driving path. 85% · published checklist
• Is there a separate ESS permit or inspection? Yes - a separate permit type and a separate, sequenced inspection. SJPermits lists 'Stationary Storage Battery System' as its own Building-Structural online permit (single-family only, marked 'Limited'), distinct from 'Solar Photovoltaic System'; the two can be applied for together in one application. Inspection is separate and comes first: 'In all cases an inspection of the bracket anchorage is required. For most systems, the anchorage must be inspected before the batteries are installed.' Where reduced spacing between residential ESS units is proposed, an SJFD Fire review is triggered on top of the Building Division permit. 76% · fire department policy
• Is a ground mount treated as a structure? Yes. A ground-mounted (non-rooftop) PV system is taken out of the by-right building-permit path entirely: 'PV projects not located on a rooftop require a Planning Permit.' It is therefore reviewed against Municipal Code Title 20 zoning development standards - setbacks, height limits - as a structure, in addition to the building permit. SJCE's public FAQ says the same: 'for non-rooftop solar system installations, a Planning Permit is required in the City of San Jose.' SJFD's PV policy adds that an elevated PV support structure with usable space underneath (min 7'-6" clear, e.g. shade or parking) must comply with the CFC with SJFD amendments as a new building, including access, hydrant location, water flow, sprinklers and extinguishers. 80% · building division bulletin
• Is there a local rule on service upgrades or busbar sizing? Yes - the City publishes explicit interconnection and busbar guidance rather than leaving it to the code book. The 2025 Residential Construction Guidelines set out the four load-side options with the exact busbar arithmetic: 100% option (busbar rating >= 1.25 x PV output current + busbar OCPD), 120% option (120% x busbar rating >= 125% x PV output current + busbar OCPD), breaker-sum option (busbar rating >= sum of OCPDs, with a required warning label), and the centre-fed panel option, plus supply-side connection rules under 705.11 (min 6 AWG Cu / 8 AWG Al, grounded conductor and main bonding jumper at the first disconnect per 250.24/250.25, and a warning that altering service equipment may void the listing and require third-party field evaluation). Separately, Directive E-001 requires an office electrical plan review for new or upgraded main services of 800 A and greater. There is a dedicated Electrical Service Panel Upgrades bulletin, and the fee schedule prices Service/Survey by amperage band. 72% · published checklist
• Is a specific mounting system or attachment spacing required? No specific proprietary mounting system and no prescribed attachment spacing for PV. What is required: for non-ballasted installations the plans must specify the method of mechanical attachment to supporting structural elements, and 'Plywood sheathing and spaced sheathing are not considered structural members' - attachment must land on rafters, trusses, purlins, beams or blocking. To qualify for an online permit the array must be non-ballasted, under 5 lb/sq ft including frame, under 40 lb concentrated load at each point of support, and no more than 18 in above the roof surface. Ballasted arrays fall out of the online path entirely. ESS is different: the City prescribes bracket anchorage details A/A-alt/B/C/D (up to 200 lb on a single stud with two #14 wood screws at 2-1/2 in embedment, 400 lb on two studs, 600 lb on three studs, 1,200 lb on floor), on 2x4 minimum full-height studs at 24 in o.c. max, braced one side by continuous construction material - or an approved SSB Masterfile on file with the Building Division. Fasteners larger than #14 wood screws require listing report approval. 78% · building division bulletin

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

• How is an inspection booked? Portal, or phone. 'Go to SJPermits.org and select "Schedule an Inspection"' - or call 408-535-3555 and select the scheduling option. Requests can be made any time of day or evening. Online scheduling needs a Customer Identification Number or Rapid Service Number from the Permit Card, or an SJPermits account. Projects with fees due or unresolved code enforcement violations cannot be scheduled online. 90% · department page
• How much notice is required? No fixed minimum notice is published. What is published is the booking window: 'You can only schedule an inspection appointment on an available inspection day within the following next 5 business days. Depending on workload, this could be several days from the date requested.' You request the next available inspection day, which may not be the next calendar day. San Jose Clean Energy's Going Solar page tells solar customers to expect inspections 'normally done onsite 10 business days after scheduling', but that page is visibly out of date elsewhere and should not be relied on. 55% · portal landing page
• Are same-day or AM/PM windows offered? Yes for a preference, no for a guarantee, and there is no same-day service. The scheduling form has a 'Prefer Time' field for morning (AM) or afternoon (PM): 'This timeframe is not guaranteed. The City may not be able to accommodate this timeframe based on workload.' On the day, the assigned inspector calls between 7:00 and 8:00 a.m.; if you answer you can discuss access, and if you do not, a message gives you a 2-hour arrival window that can start as early as 8:00 a.m. Selecting 'Prefer ETA Call' guarantees the 7-8 a.m. call with a 2 to 4 hour arrival window. Minimum inspection time is 30 minutes, of which 10 minutes is the inspector's travel, so about 20 minutes on site - 'usually adequate for projects issued an online permit'. Expedited Inspection is purchasable at $472 per hour, and inspections outside normal business hours at $472 per hour with a 4-hour minimum. 84% · department page

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

• Does this AHJ perform its own final solar inspection? Yes. Building Division inspectors perform the inspection themselves, and for single-family PV they do more than a normal final - the City Inspector performs the electrical plan review in the field on the day of inspection, because no office plan review happens. There is no delegation to a third party for residential solar. Remote Video Inspection exists as a published procedure for some work but the solar path is an on-site inspection. 85% · building division bulletin
• If delegated, to whom? Not delegated - N/A. The City of San Jose Building Division inspects its own residential solar work. The only hand-offs are to other City departments and only outside the single-family rooftop case: SJFD Fire review for PV/ESS on commercial or multifamily (3+ unit) property and for residential ESS reduced-spacing proposals, and the Planning Division for non-rooftop PV. 82% · fire department policy

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 qualifying single-family rooftop PV system: typically one inspection. The Permit Card issued at download lists the required inspection approvals, and single-family permits use a single 'Combination' inspection request covering Building, Electrical and Plumbing/Mechanical at the same address. Where a stationary storage battery is included, the bracket anchorage inspection comes FIRST and, for most systems, must happen before the batteries are installed. The full City-ordinance sequence (SJMC 24.02.520 and 24.02.530), of which only the applicable steps are marked on the Permit Card, is: foundation, under-slab/underfloor, rough (plumbing/mechanical/gas/electrical), frame, lath, insulation, fire-resistive assemblies, final. Building Final is approved only after every other inspection process on the permit has been approved. Results are recorded as OK (approved), PA (partial approval), CN (correction notice), NR (not ready) or NN (not needed). 84% · department page
• Is a rough-in or mid-roof inspection required? No mid-roof or rough inspection for a qualifying rooftop PV array - the work is not concealed and single-family PV is normally a single combination inspection. Yes for storage batteries: an inspection of the bracket anchorage is required in all cases and, for most systems, must be done before the batteries are installed. A rough inspection would only arise on a solar job that also involved concealed wiring behind finishes, since the general rough inspection is defined as happening when pipes and wires are installed 'but not concealed or covered by drywall'. 65% · building division bulletin

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

• Is there a published inspection checklist? Yes. Two published documents function as the inspection checklist for residential solar: (1) the 2025 Residential Construction Guidelines, whose 'Solar Photovoltaic Systems' section (pp. 236-242) is a checkbox list covering 690.7-690.9 calculations, 705.11-705.13 interconnection, labelling and marking, 690 installation requirements, and roof access and pathways, with a separate checkbox section for Energy Storage Systems (R330) at pp. 132-135; and (2) Bulletin #282, whose 'INSPECTION PROCESS & REQUIREMENTS' block is the eleven-item list the field inspector works to. The City warns that the Guidelines 'may be corrected or updated at any time without notification or republishing'. 80% · published checklist
• What must be on site at inspection? The Permit Card - it 'must always be on-site and available to the inspector' - plus any prior inspection notices (printed, or as files on a tablet or laptop for small projects; printed copies for larger ones). Plans and the manufacturer's installation instructions for all installed equipment. Evidence that equipment is appropriately listed and labelled to the applicable UL standards. Site-specific electrical calculations, shown on the plans and handed to the field inspector; conduit fill calculations when requested. Where an approved SSB Masterfile is used for battery bracket anchorage, construction documents matching the Masterfile. City-approved and professionally stamped plans and any pre-inspection reports where applicable. And access: all areas of the work must be reachable, with an OSHA-compliant ladder provided by the applicant - inspectors do not carry ladders. 88% · department page
• Does the inspector verify labels and listings? Yes, explicitly. 'Installed equipment is required to be listed and labeled according to applicable UL standards. Installers must provide evidence that equipment is appropriately listed/labeled and meets the code required UL standards at the time of inspection.' The manufacturer's installation instructions for all installed equipment must be available at the time of inspection, and the Inspection Success page lists 'Manufacturer listings and installation instructions' among the documents that must be ready or the inspection may be cancelled. The Residential Construction Guidelines carry a labelling checklist the inspector works through. 88% · building division bulletin

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

• What is issued on pass? Final. The inspector signs off the process on the Permit Card and, once all processes are approved, the permit status at SJPermits.org changes from 'Under Inspection' to 'Finaled'. No certificate of occupancy is involved for a rooftop solar retrofit. The signed-off permit is the document PG&E needs: PG&E defines the final electric inspection clearance as 'a signed building or electrical permit, which also includes the Final Permit Cover for all associated NEM2 generation by the authority having jurisdiction (AHJ)'. Applicants are told to retain the approved plans, inspection notices and completed Permit Card. 80% · department page
• Who notifies the utility for PTO? Installer (or the customer). The City does not notify PG&E. The contractor submits the signed-off permit as the final electric inspection clearance to PG&E - via the YourProjects-PGE interconnection portal for Standard NEM (under 30 kW solar, under 10 kW storage), or to NEMFollowups@pge.com with the application notification number if the portal cannot be used; for Complex NEM to the assigned Electric Grid Interconnection representative or Rule21Gen@pge.com. The submission must show the local AHJ, site/job address, description/summary of work, permit number, parcel (APN) number and the date signed off by the city inspector. PG&E then issues the PTO letter, which the contractor receives too if the customer authorised it on the A&A form. SJCE is told the NEM status by PG&E, not by the customer. 85% · utility DG manual
• Is there a re-inspection fee? $157.50 for the usual case - the Re-inspection Fee is $315 per hour with a 30-minute minimum charge. Related: additional inspection time can be purchased in half-hour increments through SJPermits or by phone; expedited inspection is $472/hour (30-min minimum) and out-of-hours inspection $472/hour (4-hour minimum); there is no refund for a missed inspection. 80% · fee schedule
• How are corrections issued and cleared? The inspector assigns each scheduled process a result: OK (approved), PA (partial approval), CN (correction notice), NR (not ready) or NN (not needed). Corrections are issued as a CN and published as an 'inspection notice' at SJPermits.org; the inspector also records results on the Permit Card. Prior inspection notices must be produced at the next inspection - printed for larger projects, printed or on a tablet/laptop for smaller ones. Clearing is by re-scheduling the same process through SJPermits or by phone; a re-inspection fee of $315/hour (30-minute minimum) applies. Building Final is only approved once every other process on the permit is approved. 78% · department page