City of Stockton

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 95% · department page + adopting ordinance (SMC 15.08.010, 15.10.010, 15.36.010; Ord. 2025-11-18-1206)
• What does this authority permit itself, and what does it delegate? Both 95% · adopting ordinance (SMC ch. 15.36) + department page
• Is a permit required for a residential rooftop PV system? Yes 98% · published handout (BLDG-0027 Residential Photovoltaic Installations)
• Is there a separate electrical permit, or is it combined? Combined 85% · department page (Online Permitting - permit types) + BLDG-0027 / BLDG-0054
• Is a HOA or architectural approval required first? No 95% · ordinance (SMC 15.78.050)
• Is there a historic-district review? Yes - but only inside a designated historic preservation district or on a designated landmark 72% · ordinance (SMC 16.220.060, read against 16.12.030 and 15.78.050)
• Is a wind or windstorm certification required? No 88% · adopting ordinance findings + full-code search with positive and fabricated controls
• Is a Specific Use Permit or Council approval ever required? Only on a written adverse-impact finding, and never as a routine step. SMC 15.78.050: a Building Official 'may require an applicant to apply for a use permit if the Official finds, based on substantial evidence, that the solar energy system could have a specific, adverse impact upon the public health and safety', and may deny it only on written findings that there is no feasible mitigation. Such decisions are appealable to the City Planning Commission. There is no Council approval step and no Specific/Conditional Use Permit for ordinary residential rooftop PV - SMC 16.12.030(G) exempts rooftop solar from land use permit requirements outright. 90% · ordinance (SMC 15.78.050 + 16.12.030)
• Is there a system-size cap on residential generation? No cap on residential generation. The only kilowatt figures in the code are eligibility thresholds, not limits: SMC 15.78.020 defines a 'small residential rooftop solar energy system' - the class that gets expedited, one-inspection treatment - as no larger than 10 kW AC nameplate (or 30 kW thermal) on a single- or duplex-family dwelling. BLDG-0027 sends systems over 15 kW and any system with battery storage to plan review rather than over-the-counter, and the fee schedule prices residential PV above 15 kW, which presupposes larger systems are permitted. SMC 15.04.320(C)(5) adds electrical special inspection above 100 kW. 88% · ordinance (SMC 15.78.020, 15.04.320) + fee schedule + BLDG-0027

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 92% · published handout (BLDG-0027) + Automated Solar Permitting page
• Must the contractor be registered with this authority before applying? Yes 90% · department page (Business Licenses) + BLDG-0027
• Is a homeowner permitted to self-install and self-permit? Yes 88% · published form (BLDG-0013 Owner/Builder Declaration) + BLDG-0027

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 routes. (a) SolarAPP+ (eligible retrofit rooftop residential PV, licensed contractor): SolarAPP+ approval document + SolarAPP+ approval number entered into Accela under OVER-THE-COUNTER PERMITS > OTC - Photovoltaic; the City states the BLDG-0027 submittal requirements 'are not applicable' on this route. (b) Conventional: A. Building Permit Application; B. electronic copies of PV plans; C. Owner/Builder Form if applicable; D. authorisation letter from the licensed contractor for the individual picking up the permit. Plans must contain: site plan; plan view showing PV location and existing roof framing members supporting it; mounting details, roof-covering type/number and weatherproofing; electrical single-line diagram identifying all devices and total kVA; point of interconnection with utility-supplied wiring plus main breaker, PV breaker and busbar rating; types and sizes of all conduit and conductors; manufacturer cut-sheets and installation instructions for modules, mounting systems, combiner boxes, inverters, rapid-shutdown devices and disconnects; structural calculations by a California licensed design professional if total PV weight exceeds 5 psf; and all Fire-Department-required signage shown on the plans. 95% · published checklist (BLDG-0027) + Automated Solar Permitting page
• How many copies, and in what format? Electronic only - no paper copies. PDF, direct export from CAD preferred; PDF portfolios rejected; files must be unsecured (no password/edit restrictions) and fully flattened (layers and comments); colour use limited. Each document type is a separate PDF (application, plan set, calcs). Naming convention: ProjectAddress-CYC1-Application, ProjectAddress-CYC1-Plans, ProjectAddress-CYC1-StructCalcs, with the cycle number incremented on resubmittal. Disciplines bookmarked within the plan PDF. Delivery: USB at the permit counter or email to plancheck@stocktonca.gov (in person recommended for faster processing). Resubmittals must be complete file replacements plus a written response to each correction comment - revised sheets alone are not accepted. 90% · published guide (BLDG-0046 EPC Guide) + Plan Review page
• Is a site plan required, and what must it show? Yes. BLDG-0027 requires a site plan showing the layout of the site, plus a plan view showing the location of the PV installation and the layout of the existing roof framing members that support the system - or a site plan in place of the roof plan if the panels are not roof-mounted. The City publishes a Sample Site Plan handout (BLDG-0001) and a Residential Rooftop PV Sample reference template. 92% · published checklist (BLDG-0027)
• Is a one-line / three-line diagram required? Yes 95% · published checklist (BLDG-0027)
• Are string and conductor calculations required? No 65% · published checklist (BLDG-0027), read against BLDG-0054
• Is a structural PE stamp required, and at what threshold? Yes, at a threshold of 5 pounds per square foot: 'Provide structural calculations, prepared by a California licensed design professional, if the total weight of the PV system is over five pounds per square foot.' Below 5 psf no structural stamp is required for a rooftop retrofit. Separately, floor-mounted ESS totalling 400 lbs or more requires structural details and calculations as a separate document (CBC 1603.1.8). 92% · published checklist (BLDG-0027) + BLDG-0054
• Is an electrical PE stamp required, and at what threshold? Not required for residential PV. Neither BLDG-0027 nor BLDG-0054 requires an electrical engineer's stamp at any size. BLDG-0007 confirms unlicensed individuals may design work on single-family dwellings of conventional construction. The only place a design professional is named on the electrical side is SMC 15.04.320(C)(7), which triggers electrical special inspection 'where required by the Registered Design Professional in responsible charge for the electrical design' - i.e. only if one exists on the project. 80% · adopting ordinance (SMC 15.04.320) + BLDG-0027 / BLDG-0054

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 at https://aca-prod.accela.com/STOCKTON (apply, pay, issue, upload, check status, schedule inspections), with SolarAPP+ at gosolarapp.org as the automated plan-review front end for eligible rooftop retrofits. Inspections may also be booked through the GrayQuarter 'Easy Inspection Scheduler' (apps.grayquarter.com/inspection/inspector/index?appId=1216) or the 24-hour automated phone line (209) 937-8560. A Community Development Virtual Assistant at cddvirtualassistant.stocktonca.gov estimates permit needs, costs and zoning. 95% · portal landing page / department pages
• Can the whole application be completed online? Yes 78% · department pages (Online Permitting, Plan Review, Automated Solar Permitting) + BLDG-0027
• What does a residential solar permit cost? $314.00 for a residential PV system of 15 kW or less; $450 + $15 per kW above 15 kW for larger residential systems. Percentage add-ons apply on top of the base fee: Technology Fee - Building at 0.075 of the permit fee, Community Rating System Admin Fee at 0.06 of the permit fee, General Plan Maintenance at .0015 of permit valuation, Capital Preservation at .001 of permit valuation, the State Green Building Standards pass-through ($1.00 at valuations to $25,000) and the State building-standards pass-through at .00013 of residential valuation. 90% · published fee schedule (FY 2026-27 Adopted Fee Schedule - CDD)
• How is the fee calculated? Tiered 88% · published fee schedule (FY 2026-27 Adopted Fee Schedule - CDD)
• Is there a separate plan-check fee? No 70% · published fee schedule (FY 2026-27 Adopted Fee Schedule - CDD)

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? Instant for SolarAPP+ (auto-issued on entering the approval number in Accela). Over-the-counter same day for qualifying conventional submittals. SMC 15.78.050 binds the City to issue 'the same day for over-the-counter applications or within one to three business days for electronic applications'. Projects that must go to plan review - PV over 15 kW and/or any system including battery storage - fall on the residential cycle-time table: 10 working days first review and 8 working days resubmittal under $30,000 valuation, 12 and 10 working days at or over $30,000. 90% · department handout (BLDG-0037) + SMC 15.78.050 + BLDG-0027
• How long is an issued permit valid before it expires? 365 days to start: the permit expires if the work is not commenced and at least one approved inspection recorded within 365 days of issuance. After work starts, it expires if 180 days pass between approved inspections. Renewal after expiry costs one-third of a new permit fee provided no plan changes and the lapse is under 3 years; the Building Official may grant written extensions of up to 180 days each. The Jobsite Inspection Record card prints the same 365-day rule on its face. 92% · adopting ordinance (SMC 15.04.270)
• Which utility handles interconnection here? Pacific Gas and Electric Company (PG&E) 95% · city ordinance (SMC ch. 11.04) + city inspection handout (BLDG-0115)
• Where does the utility sit in the sequence? Parallel 88% · utility process page (PG&E, Getting started with solar, Steps 2/4/5)

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 92% · adopting ordinance (SMC 15.36.010, Ord. 2025-11-18-1206 eff. 1 Jan 2026)
• Which building code edition is in force? 2025 California Building Code and 2025 California Residential Code (Title 24 Parts 2 and 2.5, on the 2024 IBC/IRC base), effective 1 January 2026 92% · adopting ordinance (SMC 15.08.010 / 15.10.010, Ord. 2025-11-18-1206)
• Which fire code edition is in force? 2025 California Fire Code, effective 1 January 2026, adopted with Appendices A, B, BB, C, CC, D, E, F, G, H, I, J, K, L, M, N, O, P and Q 90% · adopting ordinance (SMC 15.12.010, Ord. 2025-11-18-1206)
• Are there local amendments to any of the above? Yes 90% · adopting ordinance (Ord. 2025-11-18-1206, Attachment A) + codified SMC
• What is the installation judged against? The 2025 California Electrical Code (2023 NEC), principally Article 690 for the PV system and Article 705 for the interconnection, plus the City's own supplements at SMC 15.36.030-15.36.050. BLDG-0027 states plainly: 'The installation of the PV system shall conform to the requirements of CEC Article 690 and any other applicable articles or standards.' SMC 15.36.020 provides that the City's chapter controls over CEC Article 90 where they conflict. Structural, fire and energy compliance run to the 2025 CBC/CRC (CRC R329 for rooftop PV, R330 for ESS), 2025 CFC and 2025 California Energy Code. 92% · published handout (BLDG-0027) + adopting ordinance (SMC ch. 15.36)

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 2025 CRC R329.6 setbacks, reproduced in full in BLDG-0027 with diagrams. Ridge setback (R329.6.2): 18 inches clear on both sides of a horizontal ridge where the array occupies not more than 33 percent of the plan-view total roof area; 36 inches on both sides where it exceeds 33 percent. Alternative where an NFPA 13D sprinkler system is installed in the dwelling (R329.6.2.1): 18 inches at or below 66 percent coverage, 36 inches above 66 percent. Emergency escape openings (R329.6.3): no panels on the portion of roof below an emergency escape and rescue opening, and a 36-inch-wide pathway to it. DC conductor routing (R329.8.3): conduit as close as possible to the ridge, hip or valley and then directly to an outside wall; metallic conduit or raceway inside enclosed spaces; conduit run along the bottom of load-bearing members. BLDG-0027 adds two City points: all exposed roof wires/cables must be in approved conduit outside the array perimeter and before entering the building, and roof smoke-venting layouts other than the attached approved diagrams must be approved in advance by the Stockton Fire Prevention Division. 92% · published handout (BLDG-0027) quoting CRC R329.6

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 / 2025 CEC, i.e. CEC 690.12 rapid shutdown of PV systems on buildings, including the 690.12(B)(2) array-level (module-level) requirement. Stockton adopts the 2025 CEC with no local amendment to Article 690, and BLDG-0027 requires cut-sheets and installation instructions for 'rapid shutdown devices' as part of the submittal. BLDG-0054 requires ESS plans to 'Show location and/or method of rapid shutdown initiation of the ESS, when integrated with a PV system (CEC 690.12)'. 90% · adopting ordinance (SMC 15.36.010) + BLDG-0027 / BLDG-0054

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? Four layers stack at the service equipment. (1) City-specific: where the main breaker is de-rated or must hold a particular rating to satisfy CEC 705.12(B), SMC 15.36.050 requires a permanent CEC 110.21(B) label on the main service panel reading 'DO NOT UPSIZE MAIN BREAKER', or alternatively 'MAXIMUM MAIN BREAKER ALLOWED IS ____A'. (2) Code baseline: the CEC 705.10 permanent plaque or directory denoting all electric power sources on or in the premises, installed at the main service panel and at every interconnected power-production source, plus the CEC 690 marking set and CEC 408.36(D) securing of plug-in back-fed breakers. (3) ESS: where an ESS disconnecting means is provided, SMC 15.36.030(C) requires a permanent field marking of its location on or immediately adjacent to the ESS, and BLDG-0054 requires a 'permanent plaque or directory denoting location' for the disconnect within 5 feet (or 10 feet and within sight, where structural conditions require) of the main service panel. (4) Fire and utility: BLDG-0027 requires all signage required by the Stockton Fire Department per Office of the State Fire Marshal guidelines and by the California Fire and Electrical Codes; PG&E separately requires permanent signage affixed to the meter panel (see Q42). 90% · ordinance (SMC 15.36.050 / 15.36.030) + BLDG-0027 / BLDG-0054
• Does the authority specify placard wording of its own? Yes 95% · ordinance (SMC 15.36.050)
• Does it specify letter height, colour or material? Yes, and the City's spec is unusually prescriptive. BLDG-0027: 'All warning signs shall conform to the following formatting requirements: Shall be red background with white lettering; Minimum 3/8" letter height; All capital letters; Arial Font; Must be reflective, weather resistant material suitable for the environment.' That is stricter than CEC 110.21(B), which only requires durable, legible marking suitable for the environment - Stockton fixes the colour scheme, the typeface, a minimum cap height and a reflectivity requirement. PG&E layers its own material rules on top for anything affixed to the meter panel: engraved/screwed/riveted or weatherproof-adhesive identification plate with a UV rating for outdoor meters, or stencilled non-solvent paint; manufactured decals indoor only; label-maker stick-ons and handwritten lettering are unacceptable for permanent installation. 92% · published handout (BLDG-0027) + utility manual (PG&E Greenbook Table 7-7)
• Is a site plan / facility map placard required, and what must it show? Yes on both counts. Code side: CEC 705.10 requires a permanent plaque or directory denoting all electric power sources on or in the premises, installed at the main service panel and at the location of every interconnected power-production source - BLDG-0054 requires this to be shown on the plans, and the same plaque is what the inspector looks for at the service. Utility side: PG&E requires that 'Signage and maps also are required at the meter panel for the alternating current (ac) disconnect switch location when it is more than 10 feet away and out of the line of sight from the meter panel.' So a facility map is mandatory whenever the AC disconnect is remote from and not visible at the meter; where the disconnect is within 10 feet and in line of sight, the plaque alone suffices. In large meter rooms PG&E also requires a map and signage on each connected switchboard or meter stack showing where the main service breaker is. 88% · utility manual (PG&E Greenbook TD-7001M-07) + BLDG-0054
• Does the UTILITY specify placards beyond the AHJ's? Yes. PG&E adds placards the City does not ask for. (a) Generation notice: 'Customers who install distributed generation (e.g., solar, wind, battery storage) that is connected to the electric meter panel are required to install permanent signage affixed to the panel indicating an alternative source of generation is interconnected.' (b) Remote-disconnect signage and map: required at the meter panel where the AC disconnect is more than 10 feet away and out of line of sight. (c) Supply-side connections: where a fusible AC disconnect is used ahead of the main breaker and after the meter, 'Also required is an engraved placard (signage), indicating there is a line/supply side connection, installed on the metering equipment.' Material rules for all of these are PG&E's own (Table 7-7): engraved or riveted plate with UV rating outdoors, or stencilled paint; no stick-on or handwritten labels for permanent work. 90% · utility DG manual (PG&E Greenbook TD-7001M-06 / TD-7001M-07)
• Where must the labels be placed? At the main service panel: the CEC 705.10 power-source plaque or directory, and - where the main breaker is de-rated under CEC 705.12(B) - the SMC 15.36.050 'DO NOT UPSIZE MAIN BREAKER' / 'MAXIMUM MAIN BREAKER ALLOWED IS ____A' label. At every interconnected power-production source location: a further 705.10 plaque. Affixed to the meter panel: PG&E's permanent 'alternative source of generation interconnected' signage, and, for a supply-side tap, the engraved line/supply-side placard on the metering equipment. At or immediately adjacent to an ESS: field marking of the ESS disconnecting means location (SMC 15.36.030(C)), plus the BLDG-0054 permanent plaque or directory for a disconnect located within 5 feet (or 10 feet and within sight) of the main service panel. At the meter panel, additionally, the AC-disconnect location signage and map where that disconnect is over 10 feet away and out of sight. Rooftop and conduit markings follow CEC 690 in the usual places. 88% · ordinance (SMC 15.36) + BLDG-0054 + PG&E Greenbook

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, governs. Whether an AC disconnect is required at all depends on the meter panel: for inverter-based generators on a self-contained, socket-based, single-phase meter panel rated 320 A or less continuous, no AC disconnect is required (though any that is installed must be PG&E-approved); for all other self-contained or transformer-rated meter panels, and for every K-base meter panel of any ampacity, and for all non-inverter-based generators, an AC disconnect IS required. Where one is required it must meet PG&E Electric Design Standard 060559 'Disconnect Switch Requirements for Distributed Generation Customers'. On location: PG&E treats within 10 feet of and in line of sight from the meter panel as the norm - beyond that, 'Signage and maps also are required at the meter panel for the alternating current (ac) disconnect switch location when it is more than 10 feet away and out of the line of sight from the meter panel.' A supply-side (line-side) connection requires a fusible AC disconnect ahead of the main breaker and after the meter, plus the engraved line/supply-side placard on the metering equipment. City-side, SMC 15.36.030(A) requires the main disconnecting switch to be in the immediate vicinity of the meter in all cases, and on the building exterior for new buildings or major service changes; SMC 15.36.030(C) puts an ESS disconnecting means in the immediate vicinity of the main service disconnect, and BLDG-0054 sets that at within 5 feet, or 10 feet and within sight where structural conditions require. 88% · utility DG manual (PG&E Greenbook) + ordinance (SMC 15.36.030)
• Must equipment be on a specific approved list? No 68% · published handout (BLDG-0054) + BLDG-0027
• Are batteries permitted, and under what conditions? Yes, permitted, with a full submittal and conditions. BLDG-0027: 'All systems that include the installation of Energy Storage Systems (ESS) shall comply with Section R328 of the CA Residential Code' - note the handout still cites R328, which the 2025 code renumbered to R330, so the citation is stale even though the substance is right. Any PV system including battery storage loses over-the-counter eligibility and goes to plan review. Conditions from BLDG-0054 (rev. 05-06-2026): ESS must be UL 9540 listed and installed per manufacturer instructions; a dwelling containing an ESS must have interconnected smoke detectors, or a listed heat detector where smoke detection is impracticable such as an attached garage (NFPA 855); vehicle impact protection per CFC 1207.11.7.3 where the ESS sits in the normal driving path of a garage or within 36 inches left/right of it on the back wall, or within 24 inches of the back wall and 36 inches of the driving path on a side wall, with an exception where the garage opening is 7 ft 6 in or less and the ESS is at least 36 inches above the floor; the plan must state whether the system is partial-home or whole-home backup; floor-mounted ESS totalling 400 lbs or more needs structural details and calculations (CBC 1603.1.8); indoor ventilation per CEC 110.13(B) where required. A Stockton Fire operational permit is required only where a building holds more than 100 gallons of stationary or mobile energy storage capacity (SMC 15.12.020(B)), which an ordinary residential ESS does not reach. 90% · published handout (BLDG-0054) + BLDG-0027 + SMC 15.12.020
• Is there a separate ESS permit or inspection? No 75% · published handout (BLDG-0054) + Online Permitting page
• Is a ground mount treated as a structure? Yes 55% · ordinance (SMC 16.12.030(G), 15.78.020) + BLDG-0027; inference, not an express rule
• Is there a local rule on service upgrades or busbar sizing? Yes, two City-specific electrical rules bear on solar service work. SMC 15.36.030(A): 'Main disconnecting switches must be placed in the immediate vicinity of meters in all cases. On all new buildings or major service changes of all types of work, the meters and main switches shall be located on the exterior of the building at an approved location' (exceptions: an exterior shunt-trip switch, or an electrical service room with an exterior door permanently labelled 'Electrical Room'). SMC 15.36.030(C): the disconnecting means for an ESS must be in the immediate vicinity of the main service disconnect, with its location field-marked on or immediately adjacent to the ESS. SMC 15.36.050 governs the de-rated main breaker (see Q39). On busbar sizing itself Stockton adds nothing beyond CEC 705.12(B), but BLDG-0027 requires the plans to state the 'rating of bussing' and BLDG-0010 (Electrical Service Questionnaire) and BLDG-0073 (Electrical Load Calculation Worksheet) are the published forms for service changes. 90% · adopting ordinance (SMC 15.36.030) + published forms
• Is a specific mounting system or attachment spacing required? No specific mounting system or attachment spacing is mandated. BLDG-0027 requires the plans to show 'Details for mounting of PV modules, type and number of roof coverings, and subsequent weatherproofing of the roof' and to 'Provide manufacturer's cut-sheets and installation instruction for all PV modules, mounting systems, combiner boxes (if used), inverters, rapid shutdown devices, and disconnects' - i.e. the listed system is judged against its own listing and instructions, plus CRC R329 and, above 5 psf, engineered structural calculations. Nothing in SMC Title 15 prescribes a fastener pattern or spacing. 82% · published handout (BLDG-0027)

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 90% · department page + BLDG-0024 / BLDG-0025
• How much notice is required? Effectively 1 business day, set by a 3:00 p.m. cut-off. The Building Inspections page: 'Requests made before 3:00 p.m. may be scheduled for the following working day. Requests made after 3:00 p.m. and on weekends or holidays will be scheduled for the next available working day.' BLDG-0024 repeats the 3:00 p.m. cut-off for the automated line. SMC 15.04.310(B) authorises the Building Official to require requests at least twenty-four (24) hours in advance. For a qualifying small residential rooftop solar system SMC 15.78.050 is tighter and binding: 'An inspection will be scheduled within two business days of a request.' 90% · department page + ordinance (SMC 15.04.310, 15.78.050)
• Are same-day or AM/PM windows offered? No guaranteed AM/PM windows and no same-day service. AM or PM requests are entered as free text in the 'Notes to Inspector' field when booking online, or left as a voice message on the automated line, and the City is explicit that 'special requests are not guaranteed and are at the discretion of the inspector based on their overall workload and route efficiency'. Field inspection hours are Monday-Thursday 7:30 a.m. to 4:00 p.m. and Friday 7:30 a.m. to 3:00 p.m. The one hard commitment is for expedited small residential rooftop solar: SMC 15.78.050 requires the City to 'provide a two hour inspection window'. Out-of-hours work is available by paid overtime request only - conducted between 4:30 p.m. and 5:00 a.m., requested by close of business the previous working day, minimum $295 for 2.75 hours plus $104 per additional hour, and not guaranteed until paid. 88% · department page + BLDG-0025 / BLDG-0074 + SMC 15.78.050

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 95% · department page + BLDG-0074 (Building Inspectors Availability and Contact Information, rev. 05-12-2026)
• If delegated, to whom? Not delegated - N/A. The only carve-out is fire: SMC 15.78.050 contemplates that 'A separate fire inspection may be performed if an agreement with the local fire authority does not exist to perform safety inspections on behalf of the fire authority', and the jobsite inspection card carries a separate '021 FINAL FIRE' code and a 'FIRE SPRINKLERS APPROVED (BY FIRE)' checkbox under the close-in stage - both handled by the Stockton Fire Department's Fire Prevention Division, not an outside agency. Stockton Fire also approves alternate rooftop smoke-venting layouts under BLDG-0027. Nothing is delegated to San Joaquin County or to a third-party inspection firm for residential PV. 85% · ordinance (SMC 15.78.050) + BLDG-0024 / BLDG-0027

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 small residential rooftop system, one inspection: SMC 15.78.050 - 'Only one inspection shall be required and performed by the Building Department for small residential rooftop solar energy systems eligible for expedited review', done in a timely manner and consolidated. That is the 022 FINAL BUILDING inspection on the Jobsite Inspection Record, whose checklist includes a PHOTOVOLTAIC line alongside ELECTRICAL, ROOF, SMOKE DETECTORS and CARBON MONOXIDE DETECTORS. Two extra stages can be pulled in ahead of it where the work reaches them: a rough-in for concealed wiring (BLDG-0027 - 'Contact the Stockton Building Division for inspection of all attic, wall cavity, and under floor rough wiring installations before drywall, flooring, or exterior wall coverings are applied'), booked under code 012 ELECTRICAL WIRING; and, where a service or panel change is involved, code 013 ELECTRICAL SERVICE / PANEL, which checks grounding, bonding, PANEL LABELING, height and clearance and release. Sequencing is the permit holder's responsibility. 88% · ordinance (SMC 15.78.050) + BLDG-0027 + BLDG-0024 jobsite inspection record
• Is a rough-in or mid-roof inspection required? Yes - but only where the PV work conceals wiring 82% · published handout (BLDG-0027)

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 70% · department document centre (Building Forms) + BLDG-0024 jobsite inspection record
• What must be on site at inspection? The official permit record card, posted in a conspicuous place on the front premises and kept there until final approval (SMC 15.04.310(C)); the approved plans, which must be 'readily available to the inspector' - a reinspection fee may be assessed if they are not (SMC 15.04.310(H)); and a compliant ladder for any roof-mounted PV work (BLDG-0038): OSHA-standard, rated at least 250 lb, set on level slip-resistant ground, extending at least 36 inches above the roof edge, tied off at the top, feet at one quarter of ladder height from the wall, with a 2x4 in the gutter to protect it. 'If a ladder meeting the minimum requirements above is not provided, the inspection will be canceled. If a second inspection request is canceled for lack of access, a reinspection fee will be issued.' Inspectors will not walk tile roofs or pitches over 5/12 but still need ladder access to the edge. Access to the work must be provided and the work left exposed until approved (SMC 15.04.310(A) and (B)). On the SolarAPP+ route the printed SolarAPP+ approval document and City permit documents come with the permit packet. 90% · ordinance (SMC 15.04.310) + BLDG-0038
• Does the inspector verify labels and listings? Yes 85% · jobsite inspection record (BLDG-0024 p.2, OCR) + BLDG-0027 / BLDG-0054

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 88% · jobsite inspection record (BLDG-0024 p.2) + ordinance (SMC 15.04.310 / 15.04.330)
• Who notifies the utility for PTO? Installer 90% · utility process page (PG&E, Getting started with solar, Step 5)
• Is there a re-inspection fee? $195.00 per hour 90% · published fee schedule (FY 2026-27) + SMC 15.04.310(H) + BLDG-0115
• How are corrections issued and cleared? The field inspector enters results and any corrections or comments into the permit tracking system shortly after the visit; the contractor and every contact on the permit then receive an email carrying the result and a link to view the inspector's comments in the Accela portal, and an SMS as well if the inspection was booked online with texting opted in. Results can also be replayed on the automated line (209) 937-8560 by pressing [3]. Clearing them: the work is corrected and a fresh inspection is booked through the same portal or phone line - 'No work shall be done ... beyond the point indicated in each successive inspection without first obtaining the written approval of the Building Official', and non-complying portions must not be covered or concealed until authorised. Where a correction needs a drawing change rather than field work, BLDG-0115 directs that 'the Contractor or the Designer shall email the revisions to the plan checker'. If a small residential rooftop solar system fails, SMC 15.78.050 authorises a subsequent inspection that need not meet the chapter's expedited timing. 88% · department page + ordinance (SMC 15.04.310, 15.78.050) + BLDG-0115