San Joaquin 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 a property in the unincorporated county (not Mountain House, not an incorporated city) 90% · department permit page
• What does this authority permit itself, and what does it delegate? Both 90% · adopting ordinance
• Is a permit required for a residential rooftop PV system? Yes 95% · department permit page
• Is there a separate electrical permit, or is it combined? Combined — one permit 65% · fee schedule
• Is a HOA or architectural approval required first? No — and the county is forbidden from requiring it. CA Gov. Code 65850.5: a city or county 'shall not condition approval for any solar energy system permit on the approval of a solar energy system by an association'. 85% · state statute
• Is a wind or windstorm certification required? No separate wind or windstorm certification (California has no TDI-style certification scheme). Wind is handled inside the structural submittal: the checklist requires an 'engineers report for wind exposure C, seismic zone D, showing maximum rail spans, max cantilever, max down force, max uplift and lateral reactions'. 65% · published checklist
• Is there a system-size cap on residential generation? No county ordinance cap on residential generation size was located. The practical caps are route-based: SolarAPP+ accepts systems ≤38.4 kW with service rating ≤400 A, service disconnects and busbars ≤225 A, an individual battery ≤20 kWh and ESS aggregate ≤80 kWh. Anything larger, ground-mounted, ballasted, homeowner-installed, or multi-family goes through traditional plan review with no published size limit. 55% · department page + SolarAPP+ scope article (https://help.gosolarapp.org/article/43-what-types-of-systems-are-eligible-for-solarapp-review)

Several authorities require the electrical permit to be pulled by a licensed electrician, or require the contractor to be registered with them BEFORE applying. Registration is not same-day. This is second on the list rather than fourth because it is the step most likely to stop the job before the drawings matter.

• Who is allowed to pull the electrical permit? Either — a CSLB-licensed contractor (or an authorised agent of the licensee), or the homeowner as an Owner-Builder 75% · permit application terms and conditions
• Must the contractor be registered with this authority before applying? No county pre-registration for the current routes — but a SolarAPP+ account with a license verified by SolarAPP+/NREL is required for the instant-permit route 55% · department page + legacy terms document
• Is a homeowner permitted to self-install and self-permit? Yes — via the Owner-Builder route, but NOT through SolarAPP+ 80% · county form

Almost everywhere wants a site plan, a one-line or three-line electrical diagram, equipment cut sheets with listings, and a structural attachment detail. Build it against the published checklist rather than the last jurisdiction you worked in — the checklist is what the reviewer marks against.

• What documents make up a complete submittal? Traditional route (Solar (PV) Permit Checklist, extracted verbatim): (1) one completed Building Permit Application; (2) complete set of plans signed by the designer — ground mount arrays require a site plan — showing (a) property lines, buildings/structures existing and proposed, north arrow, lot dimensions, easements; (b) location of all equipment and components on plot plan; (c) all electrical equipment specifications; (d) all electrical calculations; (e) means of grounding and bonding for all equipment and support systems; (f) structural analysis of support structure if the array dead load exceeds three pounds per square foot; (g) engineer's report for wind exposure C, seismic zone D showing maximum rail spans, max cantilever, max down force, max uplift and lateral reactions, plus total weight of array and psf distributed weight; (h) Cal-Fire required setbacks shown on roof plan; (i) required placards and their locations shown on plan. SolarAPP+ route: no drawings — the contractor enters system data into the portal and the permit issues instantly. 90% · published checklist
• How many copies, and in what format? Electronic only — no paper copy count published. Submission is through the Online Permitting System (Accela) or SolarAPP+. 75% · department permit page
• Is a site plan required, and what must it show? Yes for ground mount — must show all property lines, buildings/structures (existing and proposed), north arrow, lot dimensions, easements, and the location of all equipment and components on the plot plan. A separate general Site Plan Checklist is also published. 85% · published checklist
• Are string and conductor calculations required? Yes — 'All electrical calculations' are a required plan item; the plans must also show 'means of grounding and bonding for all equipment and support systems' 80% · published checklist
• Is a structural PE stamp required, and at what threshold? Threshold is stated: 'Structural analysis of support structure is required if "dead" load of array exceeds three pounds per square foot.' Separately, an engineer's report is required for wind exposure C, seismic zone D showing maximum rail spans, max cantilever, max down force, max uplift and lateral reactions, and total array weight plus psf distributed weight. 75% · published checklist

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? Two: (1) Accela Citizen Access / Online Permitting System at permits.sjgov.org (branded 'Manage My Records'); (2) SolarAPP+ (gosolarapp.org, NREL) for eligible residential roof-mounted retrofit PV and PV+storage. Note SolarAPP+ issues its own permit number that differs from the Accela record number — inspections must be booked with the Accela number. 90% · portal landing page
• Can the whole application be completed online? Yes — application, payment and inspection scheduling are all online; solar submittals are required to be electronic 85% · department permit page
• What does a residential solar permit cost? $350.00 for a residential PV system up to 100 amps (fee includes plan review). 101–1000 amps: $525.00. Over 1000 amps: $850.00. SolarAPP+ adds a separate SolarAPP+ processing fee paid in that portal (amount not published by the county). 85% · published fee schedule
• How is the fee calculated? Tiered — by system amperage (≤100 A / 101–1000 A / >1000 A), not by valuation, kW, or panel count 90% · published fee schedule
• Is there a separate plan-check fee? No — the PV fee is inclusive: '8) Photo Voltaic Systems. (Fee includes plan review)'. Revisions are chargeable: additional plan review for revisions to approved plans, and for reviews exceeding three, is $150.00/hour; minimum fee for any plan review performed is $150.00. 85% · published fee schedule

Interconnection is a separate process from the permit and usually the longer pole. Where the utility does not depend on the permit being issued, running both at once is the single biggest saving available on a residential job.

• What is the stated plan-review turnaround? SolarAPP+ route: instant automated approval; 'Allow 1 to 2 business days for processing prior to scheduling an inspection.' Traditional plan-review route: no turnaround published. 75% · department page
• How long is an issued permit valid before it expires? 12 months. Ordinance 4686 §105.5: a permit becomes invalid unless work is commenced within 12 months of issuance, or if work is suspended or abandoned for 12 months after commencement; work is deemed suspended if no inspection has been recorded and approved within 12 months of the last approved inspection. The building official may grant extensions of not more than 180 days each. Renewal after suspension costs one-half the new permit fee (full fee if abandoned over a year, or 25% if rough inspections were approved). 85% · adopting ordinance
• Which utility handles interconnection here? Pacific Gas and Electric Company (PG&E) for essentially all of the unincorporated county. Exception: the Mountain House area is served by Modesto Irrigation District (MID) — PG&E was barred from distribution service there from 1 January 2001 by CPUC decision under Pub. Util. Code §9610. (Lodi Electric Utility is city-only and does not serve unincorporated territory.) 75% · CPUC decision + PG&E tariff service area map (https://www.pge.com/tariffs/assets/pdf/tariffbook/ELEC_MAPS_Service%20Area%20Map.pdf)
• Where does the utility sit in the sequence? Parallel — but PG&E gates the end. PG&E's NEM Interconnection Agreement (Form 79-1151A) states: 'In order for PG&E to approve your system, you will need to provide (1) this signed Agreement, (2) Application Form 79-1151B, and (3) a copy of the final signed jurisdiction approval (building permit) for your project.' A complete application requires 'Evidence of the Customer final inspection clearance from the governmental authority having jurisdiction'. 80% · utility interconnection agreement (tariff form)

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? 2025 California Electrical Code, which 'incorporates by adoption the 2023 Edition of the National Electrical Code of the National Fire Protection Association' — i.e. NEC 2023 95% · adopting ordinance
• Which building code edition is in force? 2025 California Building Code (including Chapter 1 Division II and Appendix Chapters C, I, J and Q; incorporating the 2024 IBC) and the 2025 California Residential Code. Also adopted: 2025 California Mechanical Code (2024 UMC), 2025 California Plumbing Code (2024 UPC), 2025 CALGreen (excluding Appendices A4, A5, A6.1), and the 2025 California Wildland Urban Interface Code. 95% · adopting ordinance
• Which fire code edition is in force? 2025 California Fire Code (Title 24 CCR Part 9), incorporating the 2024 International Fire Code — adopted by a separate ordinance, No. 4687, into Title 4 Public Safety, Division 1 Fire Prevention 95% · adopting ordinance
• Are there local amendments to any of the above? Yes — but none of them touch solar. Ordinance 4686 amends CBC Ch.1 Div.II administrative sections (104.7 records, 105.2 exempt work, 105.3.2, 105.5 expiration, 107.2.6.1, 107.3.1, 109.2/109.3/109.4/109.6 fees, 110.3.12.1, 110.5 inspection requests, 111.1/111.2 certificate of occupancy), deletes §108 and §116, and replaces §113 with a local Building Board of Appeals. Ordinance 4687 amends CFC §503.1 (fire apparatus access roads, to the San Joaquin County Fire Chiefs Association standard), §§315/2810 (pallet and lumber yards), and adds local explosives/fireworks and cost-recovery provisions. 90% · adopting ordinance
• What is the installation judged against? The 2025 California Electrical Code (NEC 2023) as adopted by Ordinance 4686 §8-1013, administered under CBC Chapter 1 Division II as locally amended (§8-1013.1). No local technical amendments to the electrical code. 90% · adopting ordinance

Ridge setbacks and roof access pathways are fire-service requirements and they constrain the array layout. They are the most common cause of a redesign after the fire department comments on a plan set.

• What ridge setback and access pathways are required? The county requires setbacks to be drawn but publishes no dimensions of its own: Solar (PV) Permit Checklist item 2(h) — 'Show Cal-Fire required setbacks on roof plan.' The governing dimensions therefore come from the adopted 2025 California Fire Code and 2025 California Residential Code (ridge setback and access/smoke-ventilation pathways), which Ordinance 4687 adopts with NO solar-specific local amendment. 70% · published checklist + adopting ordinance

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

• Is rapid shutdown required, and to which NEC edition? Yes — to the 2025 California Electrical Code, which incorporates NEC 2023 (Art. 690.12 rapid shutdown). No local amendment or exception. 80% · adopting ordinance

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 requires placards but does not enumerate them: Solar (PV) Permit Checklist item 2(i) — 'Show required placards and their locations on plan.' The actual set therefore comes from (a) the 2025 CEC / NEC 2023 Articles 690 and 705 as adopted, and (b) PG&E, which requires permanently attached signage on the front of the AC disconnect reading e.g. 'UTILITY AC DISCONNECT SWITCH', open/closed position marking on the switch, and NGOM labelling where a net generation output meter is installed. 75% · published checklist + utility Greenbook doc 060559
• Does the authority specify placard wording of its own? No 75% · published checklist + adopting ordinances
• Does it specify letter height, colour or material? Nothing from the county. From PG&E (governs the utility AC disconnect label): '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.' 85% · utility Greenbook standard (doc 060559 Rev. #07)
• Is a site plan / facility map placard required, and what must it show? The county requires placard LOCATIONS to be shown on the submitted plan (checklist item 2(i)) but specifies no site-plan/facility-map placard of its own. PG&E requires a map placard in two situations: 'When the disconnect switch is not grouped with the meter panel provide a map showing the location', and 'If a Net Generation Output Meter (NGOM) is installed provide proper labeling as described and a map showing the location if not grouped together with the other meter(s) and disconnect switch.' Also: 'If the device is not adjacent to the PG&E's electric revenue meter(s), a clear map and signs indicating of the location of the disconnect switch are required. If the disconnect switch is not accessible outside the locked premises, include signs with contact information and a distribution provider-approved locking device.' 70% · utility Greenbook standard (doc 060559 Rev. #07)
• Does the UTILITY specify placards beyond the AHJ's? Yes — PG&E requires beyond the AHJ: (1) permanently attached signage on the front of the AC disconnect explaining it is the ac disconnect switch for the generation, example 'UTILITY AC DISCONNECT SWITCH'; (2) marking or signage on the switch clearly indicating open (off) and closed (on) positions; (3) engraved phenolic or ANSI Z535.4 material, minimum 3/8" lettering, all capitals; (4) a location map where the disconnect is not grouped with the meter panel; (5) NGOM labelling and map where a net generation output meter is fitted; (6) the disconnect 'clearly marked on the submitted single-line diagram indicating the manufacturer, model type, voltage rating, current rating, and location'. 90% · utility Greenbook standard (doc 060559 Rev. #07)
• Where must the labels be placed? PG&E label: permanently attached on the FRONT of the AC disconnect switch enclosure. Position marking: on the switch itself. Where the disconnect is not grouped with the meter panel, a location map is additionally required. County: locations are not prescribed — they must simply be shown on the submitted plan and are then judged against the plan at inspection. 75% · utility Greenbook standard + county 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 requirement — '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'; or in an approved electric meter room within the same 10 feet and line of sight. If outdoors with the meter it must be at the same grade level. NOT allowed on any floor or level above grade, on a roof, or in a room that is not an approved electric meter room. Mounting height 48 inches minimum to 75 inches maximum, ground to top of enclosure. Must be installed between the PG&E meter and all generation sources, must isolate generation only (not customer loads), and must accept a PG&E padlock with a 5/16-inch shaft (keyed locks not allowed). EXEMPTION: inverter-based systems on PG&E single-phase services up to 240 V may be exempted, as PG&E determines, if the meter panel is self-contained (not transformer-rated), accepts form 'S' socket-based meters (not bolt-on), is rated CL 320 or less continuous, and is single-phase 120/240 V or 120/208 V. 90% · utility Greenbook standard (doc 060559 Rev. #07)
• Must equipment be on a specific approved list? No county approved-equipment list. PG&E does maintain one for the AC disconnect: 'PG&E-approved disconnect switch models, rated up to 1200 amps, currently listed in both the Eaton and Siemens Safety Switch Cross-Reference Guides, meet all of the functional requirements' — published on PG&E's Distribution Interconnection Handbook site (pge.com/dih). General equipment must be listed by UL or another NRTL. 65% · utility Greenbook standard
• Are batteries permitted, and under what conditions? Yes, permitted. Solar-plus-storage can go through SolarAPP+ (the county links the IREC 'How to Use SolarAPP+ For Solar and Storage Projects' training and requires it before submitting storage projects). SolarAPP+ eligibility limits: individual battery ≤20 kWh, ESS aggregate ≤80 kWh depending on where the batteries are installed. Substantively judged against the 2025 California Fire Code (Ord. 4687) and 2025 CRC/CBC as adopted, with no solar- or ESS-specific local amendment. 65% · department page + SolarAPP+ scope article
• Is there a separate ESS permit or inspection? No separate ESS permit for a combined solar-plus-storage project through SolarAPP+ — one permit and one inspection checklist covers both 50% · department page + fee schedule
• Is a ground mount treated as a structure? Yes — a ground-mounted array needs a Building Permit in its own right and is treated structurally. The solar page lists 'Ground-mounted solar arrays' as requiring a Building Permit; the checklist requires a site plan showing property lines, existing and proposed structures, north arrow, lot dimensions and easements, plus structural analysis of the support structure and an engineer's report for wind exposure C / seismic zone D. Ground mounts are outside SolarAPP+ scope and must go through traditional plan review. 80% · department permit page + published checklist
• Is a specific mounting system or attachment spacing required? No specific mounting system or attachment spacing is prescribed. Performance-based instead: the engineer's report must show 'maximum rail spans, max cantilever, max down force, max uplift and lateral reactions', plus total array weight and psf distributed weight; structural analysis of the support structure is triggered when array dead load exceeds 3 psf. 70% · published 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? Portal or Phone — online through the permitting system at permits.sjgov.org, or by calling the 24-hour inspection recorder on (209) 468-3165. Ordinance 4686 §110.5 also allows a written request. For a SolarAPP+ permit, book with the Accela record number, NOT the SolarAPP+ permit number. 90% · department page
• How much notice is required? About one business day. Verbatim: 'Inspection requests received before 3:00 p.m. will be made on the next business day; requests received after 3:00 p.m. will be done the day following.' Ordinance 4686 §110.5: 'The building official may require that every request for inspection be filed at least one working day before such inspection is desired.' Cancellations by phone must be called in before 9:00 a.m. on the day; online reschedules must be made before 12:00 AM one day prior. For a SolarAPP+ permit, allow 1–2 business days after issuance before the record is schedulable. 90% · department page + adopting ordinance

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 — San Joaquin County CDD Building Inspection Division performs its own inspections 85% · department page + adopting ordinance
• If delegated, to whom? Not delegated — the county's own Building Inspection Division inspects; contact (209) 468-3165 / building@sjgov.org, 1810 E. Hazelton Ave, Stockton CA 95205 80% · department page

A rough-in or mid-roof inspection, where one is required, has to happen before the work it covers is closed up. Missing a stage means opening something back up, and it is the most expensive kind of correction.

• Which inspections are required, and in what order? One inspection. CA Gov. Code 65850.5: for a small residential rooftop solar system eligible for expedited review, 'only one inspection shall be required, which shall be done in a timely manner and may include a consolidated inspection', with the sole exception of a separate fire safety inspection where the jurisdiction has no agreement with the local fire authority. The SolarAPP+ route is consistent: a single inspection against the project's SolarAPP+ Permit and Inspection Checklist. Ground-mount and other traditional-route projects are not covered by that one-inspection rule and will follow the normal footing/rough/final sequence. 75% · state statute + county SolarAPP+ page
• Is a rough-in or mid-roof inspection required? No — not for an eligible small residential rooftop system, where state law allows only one (possibly consolidated) inspection 70% · state statute

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 — for the SolarAPP+ route, a project-specific 'Permit and Inspection Checklist' is generated at permit issuance: 'Download and print the Permit and Inspection Checklist. These must be on the jobsite at the time of inspection.' For the traditional route, the county publishes the Solar (PV) Permit Checklist, but that is a submittal checklist, not an inspection one. 80% · department page
• What must be on site at inspection? (1) The SolarAPP+ Permit and Inspection Checklist, printed — 'These must be on the jobsite at the time of inspection.' (2) The approved construction documents: Ordinance 4686 §107.3.1 — one approved set 'shall be kept at the site of work and shall be open to inspection by the building official or a duly authorized representative'. (3) The printed, signed permit and inspection record list, posted at the job site. 80% · department page + adopting ordinance + permit terms

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. For a one- or two-family dwelling no separate certificate is issued: Ordinance 4686 §111.1 Exception 2 — 'For one- and two-family dwellings and their accessory structures, a building permit with an approved final inspection shall be considered the certificate of occupancy.' The approved final is then what PG&E accepts as the 'final signed jurisdiction approval'. 85% · adopting ordinance
• Who notifies the utility for PTO? Installer (or the customer, or an authorised third party acting for them) — NOT the AHJ. PG&E: 'In order for PG&E to approve your system, you will need to provide (1) this signed Agreement, (2) Application Form 79-1151B, and (3) a copy of the final signed jurisdiction approval (building permit) for your project.' A complete application requires 'Evidence of the Customer final inspection clearance from the governmental authority having jurisdiction over the generating system.' PG&E then issues the PTO letter. 80% · utility interconnection agreement (tariff form)
• Is there a re-inspection fee? $150.00 each — 'Additional fee that may be charged after two consecutive failed inspections of the same item' 90% · published fee schedule