City of Ione

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 92% · department page
• What does this authority permit itself, and what does it delegate? Both 88% · department page + permit application form
• Is a permit required for a residential rooftop PV system? Yes 95% · published checklist
• Is there a separate electrical permit, or is it combined? Combined 80% · fee schedule + permit application form
• Is a HOA or architectural approval required first? No city-required HOA/architectural approval found 62% · published checklist (absence)
• Is there a historic-district review? No, for single-family residential -- and Yes only within a narrow downtown zone for non-residential/mixed-use structures. IMC §17.28.020 establishes a Historic Overlay (H) district limited to the portion of Main Street between Ione Street and Sacramento Street, requiring architectural design review for development within it, BUT §17.28.020(B)(3) explicitly states: 'those buildings used exclusively and solely for residential uses (e.g., single family residential) are hereby exempted from the requirement of architectural design review.' 88% · codified ordinance
• Is a wind or windstorm certification required? No separate windstorm certification program (California does not run a TDI-style program); instead the city's own PV checklist directly requires the applicant to 'demonstrate that roof mounted systems are designed for wind loads in accordance with CBC 1510.7' as a plan-review item. 78% · published checklist
• Is a Specific Use Permit or Council approval ever required? Yes, for ground-mounted/free-standing systems only -- the city's own PV Solar Checklist states under 'Ground-Mount System': '(Planning approval required for free standing system.)' Roof-mount systems carry no equivalent trigger in the checklist, and Zoning Code §17.38.030 (Accessory Structures) generally routes only 'certain structures' needing site plan review, variance, or other Ch.17.10 entitlements beyond the base building permit. 80% · published checklist + codified ordinance
• Is there a system-size cap on residential generation? No residential system-size (kW) cap found anywhere 68% · codified ordinance (absence)

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 62% · permit application form
• Must the contractor be registered with this authority before applying? Likely yes, but not confirmed as a hard gate on permit issuance specifically for solar 55% · permit application form + fee schedule (inference)
• Is a homeowner permitted to self-install and self-permit? Yes 75% · permit application 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? Per the city's own Photovoltaic Solar Checklist (dated 5 Feb 2026): a cover sheet (project address, owner contact, plan preparer name/address/phone/signature with engineer's seal and/or CSL# where applicable, list of applicable codes, scope of work, sheet index, legend); an electrical single-line diagram with total kVA rating; main/subpanel location and amperage with make/model (Zinsco panels must be upgraded); roof-covering type and waterproofing method; conduit routing (above/below roof, labeling <10ft apart per CEC 690.31(G)(4), wire type/size/count, standoff/support details); manufacturer specs/installation instructions for modules, mounts, inverters, disconnects, batteries; grounding-system details; structural roof-framing plan and array-support layout; and (if ground-mount) a plot plan, footing/foundation details, and clear-brush-area plan; (if battery) a floor plan of the housing structure and battery specs. 93% · published checklist
• How many copies, and in what format? Plans submitted electronically by email to building@ione-ca.com, each file as a SEPARATE PDF attachment (not one combined PDF), unlocked/not password protected; standard paper sizes 8.5x11.5 or 11x17 are acceptable if hard copies are requested by the Senior Building Inspector, Planning Department, or Fire Chief. Paper mail submittal is described as 'discouraged'. 88% · department page + published checklist
• Is a site plan required, and what must it show? For ground-mount systems: yes -- a plot plan showing property boundaries, all buildings on the parcel, and easements (Planning approval is separately required for a free-standing system). For roof-mount systems, no distinct 'site plan' is itemized beyond the cover sheet's project-address/scope-of-work items; siting is instead conveyed via the roof plan and single-line diagram. 68% · published checklist
• Is a one-line / three-line diagram required? Yes 92% · published checklist
• Are string and conductor calculations required? Partially -- the checklist requires conduit/conductor sizing detail (type, size, and number of wires in each conduit) and a total kVA rating on the single-line, but it does not itemize a distinct string-level Isc/Voc/temperature-coefficient/voltage-drop calculation the way some larger CA jurisdictions' checklists do. 65% · published checklist
• Is a structural PE stamp required, and at what threshold? Yes -- structural calculations by a licensed/registered California design professional are required for the existing roof structure if the total combined weight of all roof-mounted PV equipment exceeds 5 pounds per square foot. 90% · 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? No dedicated online permit portal (no Accela/eTRAKiT/SolarAPP+/OpenGov found). The city's process is email-based: applications and plans are submitted to building@ione-ca.com; plan-check deposits are paid by phone (credit card preferred) or mailed check. 82% · department page
• Can the whole application be completed online? No 78% · department page
• What does a residential solar permit cost? Residential roof-mount: 1.25% of project valuation, $165.00 minimum. Residential ground-mount: 1.5% of project valuation, $275.00 minimum. Plus a separate plan-review fee (see q17): 65% of the permit fee, $220.00 minimum. 90% · published fee schedule
• How is the fee calculated? Valuation 90% · published fee schedule
• Is there a separate plan-check fee? Yes 92% · 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.

• How long is an issued permit valid before it expires? 2 years from date of issuance, OR sooner if work is not commenced within 180 days of issuance, OR if work is suspended/abandoned (defined as no documented progress inspection for more than 180 days). 92% · codified ordinance
• Which utility handles interconnection here? Pacific Gas & Electric (PG&E) 92% · department page
• Where does the utility sit in the sequence? After permit (parallel-with-a-gate, more precisely): PG&E's Electric Rule 21 (Section D.13.b) requires 'evidence of Applicant's final electric inspection clearance from the Governmental Authority having jurisdiction over the Generating Facility' as one of three conditions before PG&E will normally process Permission to Operate within its 30-business-day target. Ione's own Municipal Code has no local utility-connection ordinance of its own (unlike Amador County's §15.04.080) -- this is entirely a PG&E-tariff-level requirement. 85% · utility tariff

The NEC edition a jurisdiction enforces is often a cycle behind the newest one published, and local amendments sit on top of it. Rapid shutdown, conductor sizing and labelling all change between editions, so the edition in force is the first thing to establish, not the last.

• Which NEC edition is in force? 2023 NEC (as incorporated into the 2025 California Electrical Code), per the city's own live PV Solar Checklist, which states design/installation must comply with 'the 2025 California Building Code (CBC), California Residential Code (CRC), California Electrical Code (CEC), and California Fire Code (CFC).' HOWEVER: the codified Municipal Code chapter (§15.12.010, Ord. No. 509, 12-3-2019, current through Municode Supp. 13 / Nov 2023) still literally reads 'The 2019 edition of the California Electrical Code... based on the 2017 National Electrical Code' -- a real, dated lag between the codified adoption ordinance and the department's current live guidance. Under CA Building Standards Law the state's current triennial cycle (2025, effective statewide 1 Jan 2026) generally supersedes a stale local base-cycle citation via the ordinance's own 'and all future amendments thereto' clause, which is why I record 2023 as the operative answer, but the literal codified text has not been updated to say so. 75% · published checklist vs. codified ordinance (conflicting)
• Which building code edition is in force? 2025 California Building Code, per the city's own live PV Solar Checklist. The codified Municipal Code chapter (§15.04.010, Ord. No. 507, 12-3-2019) still literally reads 'The 2019 edition of the California Building Code... based on the 2018 International Building Code' -- same lag noted at q29. 75% · published checklist vs. codified ordinance (conflicting)
• Which fire code edition is in force? 2025 California Fire Code, per the city's own live PV Solar Checklist. The codified Municipal Code chapter (§15.22.010, Ord. No. 489, 3-7-2017) is the most stale of all four: it still literally reads 'The 2016 edition of the California Fire Code... based upon the 2015 edition of the International Fire Code.' 72% · published checklist vs. codified ordinance (conflicting)
• Are there local amendments to any of the above? Yes 92% · codified ordinance
• What is the installation judged against? The adopted 2025 CBC/CRC/CEC/CFC (per the live checklist) as locally amended, plus UL listing/labeling (UL 1703 for panels/modules), IEEE/accredited-lab standards, and PG&E Electric Rule 21's interconnection design requirements (visible disconnect, markings). 80% · published checklist + utility tariff

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? Codified: CRC §R324.6.1 (locally added, Ord. 508) requires a pathway of not less than 36 inches wide, setback from the lowest roof edge, on any roof plane with a PV array. The city's own PV Solar Checklist separately states (citing 'local fire district requirements'): minimum 3 feet (36 inches) setback from roof edges, hip roof layouts, eaves and parapets; and minimum 18 inches setback where panels are placed on both sides of a hip or valley. 90% · codified ordinance + 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? Not stated in the city's own PV Solar Checklist (no mention of 'rapid shutdown' or '690.12' anywhere in the document, control-checked). It applies indirectly through the state-adopted 2025 CEC (based on the 2023 NEC per the live checklist's own code-cycle statement -- see q29), which carries NEC Article 690.12 forward without a local exception found anywhere in Title 15. 68% · published checklist (absence) + code adoption (inference)

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? Per the PV Solar Checklist: (1) equipment placards identifying all installed equipment ('Placards shall identify all equipment installed with PV Panels identified'); (2) conduit/wiring labels required every <10 feet along the wiring system per CEC 690.31(G)(4); (3) a 'Do Not Relocate This Breaker' sign at the backfed breaker location (per CEC 690.64/705.129(D)(2)(3)(b)); (4) directional placards to inverters and the main service panel when the inverter is not in line of sight of the MSP or is in a non-readily-accessible space. 85% · published checklist
• Does the authority specify placard wording of its own? Yes, in part 78% · published checklist
• Is a site plan / facility map placard required, and what must it show? Yes, conditionally -- when an inverter is not in line of sight of the main service panel/PV overcurrent device, or is located in a non-readily-accessible area (lockable garage, room, yard, etc.), the checklist requires 'placards with directional signage to inverters and MSP' -- functioning as a wayfinding/facility placard, though the city does not describe a distinct NEC-705.10-style single consolidated facility map/directory placard beyond this directional-signage requirement. 65% · published checklist
• Does the UTILITY specify placards beyond the AHJ's? Yes -- PG&E's Electric Rule 21 (Section H.1.d, 'Visible Disconnect Required') independently requires the Producer to furnish and install a ganged, manually-operated isolating switch near the Point of Interconnection, which must allow visible verification of separation, include open/closed markings/signage, and be reachable 24/7 by Distribution Provider personnel without obstacles, keys, or special clearance -- a statewide PG&E requirement layered on top of anything the City requires. 88% · utility tariff
• Where must the labels be placed? At the service equipment/point of interconnection and on the visible AC disconnect (per PG&E Rule 21's disconnect-marking requirement, q42); conduit/wiring labels every <10 feet along the run per CEC 690.31(G)(4); a 'Do Not Relocate This Breaker' placard adjacent to the backfed breaker; and directional placards toward the inverter/MSP where not in line of sight, per the city's own PV Solar Checklist. 80% · published checklist + utility tariff

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.

• Must equipment be on a specific approved list? Yes 88% · published checklist
• Are batteries permitted, and under what conditions? Yes, permitted, under conditions set out in the city's own PV Solar Checklist's 'Battery Installation' section: provide a floor plan of the structure housing the battery bank; indicate battery type, size, dimensions, ventilation, and physical-damage protection; provide the battery-bank anchoring method and a wiring diagram of the battery set; and the disconnect must be located within 10 feet of the main service panel. 85% · published checklist
• Is there a separate ESS permit or inspection? No separate ESS-specific permit or fee line found 65% · fee schedule (absence)
• Is a ground mount treated as a structure? Yes 78% · published checklist
• Is a specific mounting system or attachment spacing required? No city-mandated proprietary mounting system. The city requires the plans to specify the manufacturer-specific attachment method (bolt/lag style, diameter, embedment) and, for structural load distribution, to 'stagger the placement of (other than ends) supports... to properly distribute loads and avoid concentrated loading. Otherwise, provide engineering to verify the roof structure is capable of supporting in-line supports.' 82% · 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? Phone, Email, or Walk-in 85% · 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 85% · department page
• If delegated, to whom? N/A -- not delegated; the City performs its own final solar inspection (see q52). 78% · 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? Roof-mount residential PV: a single final inspection. Ground-mount residential PV: footing inspection, then final. (Commercial roof-mount: final only; commercial ground-mount: footing then final.) 88% · published fee schedule
• Is a rough-in or mid-roof inspection required? No 82% · published fee schedule

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 82% · published checklist
• What must be on site at inspection? A sturdy, non-folding, non-telescoping extension ladder secured to and extending at least 2 feet above the roof (and a matching ladder extending into the attic access, if applicable); the contractor present for all inspections; and the attic, all equipment, disconnects, and the main and subpanels open and ready for inspection before the inspector arrives. 88% · published checklist
• Does the inspector verify labels and listings? Likely yes, inferred rather than explicitly stated -- the PV Solar Checklist requires equipment to be UL-listed and labeled, requires placards identifying all installed equipment, and separately instructs that 'the contractor will be present for all inspections, and have attic, and all equipment, disconnects, and main and subpanels open and ready for inspection prior to arrival of inspector' -- but no city document states in so many words that the inspector specifically checks labels/listings as a discrete step. 60% · published checklist (inference)

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 82% · published fee schedule
• Who notifies the utility for PTO? Installer/Applicant 82% · utility tariff
• Is there a re-inspection fee? $110.00 per inspection 92% · published fee schedule + codified ordinance
• How are corrections issued and cleared? If work does not pass inspection, the inspector issues a correction notice; once corrections are made, the customer must reschedule an inspection (a re-inspection fee and any charges for the new scope apply). 85% · department page