City of Los Banos

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% · authority's own ordinance
• What does this authority permit itself, and what does it delegate? Both (Building & Electrical, combined into a single permit for solar) 82% · authority's own page + fee schedule + RFQ record
• Is a permit required for a residential rooftop PV system? Yes 95% · authority's own ordinance
• Is there a separate electrical permit, or is it combined? Combined 62% · fee schedule (dated; see q15 note)
• Is a HOA or architectural approval required first? No 80% · authority's own ordinance
• Is there a historic-district review? No 85% · authority's own ordinance (full TOC read by name)
• Is a wind or windstorm certification required? No 55% · absence in authority's own ordinance + general CA code structure
• Is a Specific Use Permit or Council approval ever required? Yes, conditionally — the Chief Building Official may require an Administrative Use Permit if the official finds, on substantial evidence, that the system 'could have a specific, adverse impact upon the public health and safety'; denial or conditions are appealable to the Planning Commission. 90% · authority's own ordinance
• Is there a system-size cap on residential generation? No hard cap on residential system size, but only systems ≤10kW AC nameplate (or ≤30kW thermal) on a single- or duplex-family dwelling qualify as a 'small residential rooftop solar energy system' eligible for the ministerial, same-day/1-3-day Ch. 8-6 process; larger systems fall outside that expedited ordinance and would need standard discretionary/administrative review. 85% · authority's own ordinance

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 55% · authority's own page (permit application list)
• Must the contractor be registered with this authority before applying? No 65% · authority's own page
• Is a homeowner permitted to self-install and self-permit? Yes 55% · authority's own page (application list) + res. permit packet

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? For systems ≤10kW AC / 30kW thermal on a 1- or 2-family dwelling: Symbium's online compliance questionnaire plus uploaded plans/documents (LBMC §8-6.05(a)-(c)); larger or non-qualifying systems use the standard Residential Building Permit Application packet plus digitally-submitted plans. 65% · authority's own ordinance + authority's own page
• How many copies, and in what format? Electronic/digital submittal only — PDF compatible with Adobe Acrobat 9.0, combined into one or two indexed/bookmarked packages, emailed to losbanosbldg@csgengr.com for a web-upload link; the City's packet formerly required 3 paper copies before the 2020 digital-submittal policy. 80% · authority's own handout (PDF, text-layer, extracted with pdftotext)
• Is a site plan required, and what must it show? A site plan is required as part of the standard plan set for non-Symbium submittals (Digital Plan Check Handout requires 'fully dimensioned' plans, foundation/floor/roof framing); the specific content a PV site plan must show is not separately published — LBMC §8-6.05(d) instead defers to the standard plans/checklist in the state's California Solar Permitting Guidebook without republishing that content locally. 55% · authority's own ordinance + handout
• Is a one-line / three-line diagram required? Yes (inferred) 55% · inference from ordinance's Guidebook-conformance clause
• Are string and conductor calculations required? Yes (inferred) 50% · inference from ordinance's Guidebook-conformance clause

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? Symbium (symbium.com/instantpermitting) for small residential rooftop solar and/or battery storage ≤10kW AC/30kW thermal; other/non-qualifying submittals go through the Building Department's email-based digital plan-check process (losbanosbldg@csgengr.com) rather than a named commercial permit portal (no Accela/Citizenserve/EnerGov branding found on the City's site). 78% · authority's own page
• Can the whole application be completed online? Yes (for Symbium-eligible solar/battery systems) 90% · authority's own page
• What does a residential solar permit cost? Residential – Under 10kW: $194.00 plus plan-check fee. 10.1–15kW: $194.00 + $21.80/kW above 10.1kW, plus plan-check fee. 15.1kW and up: $303.10 + $15.00/kW above 15.1kW, plus plan-check fee. 68% · fee schedule (dated 2019, city-labelled 'CURRENT')
• How is the fee calculated? Tiered by kW nameplate rating (3 residential bands: <10kW, 10.1-15kW, >15.1kW), each plus a separate plan-check fee. 68% · fee schedule (dated 2019, city-labelled 'CURRENT')
• Is there a separate plan-check fee? Yes — Plan Check Fee = 65% of the Permit Fee, 'When Required' (a standalone line item in the general Building fee table, applicable to solar permits per the 'Plus plan check fee' notation on each Solar Energy Fee tier). 75% · 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? Same day for over-the-counter applications; 1 to 3 business days where over-the-counter approval isn't authorized or feasible. 92% · authority's own ordinance
• Which utility handles interconnection here? Pacific Gas & Electric (PG&E) 62% · absence of municipal utility billing (city's own page) + absence of a Merced-County CCA (secondary source)
• Where does the utility sit in the sequence? After permit — Permission to Operate (PTO) is not released until PG&E has 'evidence of Applicant's final electric inspection clearance from the Governmental Authority having jurisdiction.' 82% · utility tariff (PDF, text-layer, extracted with pdftotext)

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

• Which NEC edition is in force? 2023 NEC via the 2025 California Electrical Code, in force statewide since 1 Jan 2026. The City's own codified text (LBMC §8-1.07) still names the '2022 California Electrical Code' (built on the 2020 NEC) as of the last eCode360 recodification (dated 2025-03-05 on the code viewer) — a codification lag rather than evidence the City has opted out of the new cycle. 62% · authority's own ordinance (dated; codification lag noted)
• Which building code edition is in force? 2022 California Building Code per the City's own codified LBMC §8-1.01 (last recodified 2025-03-05 per eCode360); the state-mandated 2025 CBC took effect 1 Jan 2026 and applies by operation of state law even though the City's local text has not yet been updated to say so. 68% · authority's own ordinance (dated; codification lag noted)
• Which fire code edition is in force? 2022 California Fire Code per LBMC §4-3.01 (Ord. 1200, eff. Nov. 19, 2022), same codification-lag caveat as q29/q30 for the state-mandated 2025 cycle. 68% · authority's own ordinance (dated; codification lag noted)
• Are there local amendments to any of the above? Yes for fire — the City has adopted local amendments to the 2022 CFC (Ord. 1200, eff. 11/19/2022, and predecessors back to Ord. 1066); however none of the 13-page amendment attachment addresses solar PV, battery/ESS, or rooftop access/setbacks — confirmed by reading the full attachment. No PV-specific local amendment to the CBC/CRC/CEC was found either; the solar-specific local rule is the separate ministerial ordinance at Ch. 8-6, not an amendment to the base codes. 82% · authority's own ordinance attachment (PDF, text-layer, extracted with pdftotext)
• What is the installation judged against? The adopted 2022 CBC/CRC/CEC/CFC (as locally amended, though amendments don't touch PV) plus LBMC Ch. 8-6's own health/safety-only review standard; for electricity-producing systems specifically, LBMC §8-6.04(c) requires compliance with 'the California Electrical Code, the Institute of Electrical and Electronics Engineers, and accredited testing laboratories such as Underwriters Laboratories.' 78% · authority's own 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? Not fewer than 2 pathways (36 in. min. width) from lowest roof edge to ridge on separate roof planes, at least one on the street/driveway side; ridge setback of 18 in. clear on both sides of the ridge where the PV array occupies ≤33% of plan-view roof area, or 36 in. clear where it occupies more than 33%. 75% · state-adopted model code (2022 CRC, ICC official viewer) + confirmed absence of local amendment

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

• Is rapid shutdown required, and to which NEC edition? Yes — rapid shutdown is required under NEC §690.12, via the 2020 NEC as adopted in the currently-codified 2022 CEC (LBMC §8-1.07); the 2025 CEC (2023 NEC), in force statewide since 1 Jan 2026, retains §690.12 under the same section number. 65% · inference from adopted code edition

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? No City- or Fire-Department-specific PV placard beyond what the adopted NEC itself requires (e.g. §690.56/§705.10 labeling) — confirmed by reading LBMC Ch. 8-6 in full and the entire 2022 CFC local-amendments attachment, neither of which mentions placards for PV. Separately, PG&E's own Greenbook requires an engraved placard on the metering equipment, but only where a line-side/supply-side tap AC disconnect is used (see q42). 72% · absence confirmed by full-text read of authority's own ordinance + amendment attachment
• Does the authority specify placard wording of its own? No 72% · absence confirmed by full-text read
• Does it specify letter height, colour or material? No 68% · absence confirmed by full-text read
• Does the UTILITY specify placards beyond the AHJ's? Yes — PG&E requires an 'engraved placard (signage), indicating there is a line/supply side connection, installed on the metering equipment' whenever a fusible AC disconnect is used ahead of the main breaker for a line-side/supply-side tap. 82% · utility manual (PDF, text-layer, extracted with pdftotext)
• Where must the labels be placed? On the metering/service equipment itself — PG&E's line/supply-side-connection placard is required to be 'installed on the metering equipment' per its Greenbook; the City has no separate label-placement rule of its own (see q38-40). 72% · utility manual (PDF)

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? For the typical residential case (self-contained meter panel, 320A or less, single-phase), PG&E does NOT require an AC disconnect at all. An AC disconnect IS required for all other self-contained/transformer-rated meter panels and for any non-inverter-based generator; where a line-side/supply-side tap is used, a fusible AC disconnect must be installed ahead of the main breaker and after the meter. 82% · utility manual (PDF, text-layer, extracted with pdftotext)
• Must equipment be on a specific approved list? No dedicated City-approved equipment list; instead LBMC §8-6.04(b)-(c) requires accredited-listing-agency certification (water heating systems) and CEC/UL/NRTL-standard compliance (electricity-producing systems) as the generic listing requirement. 78% · authority's own ordinance
• Are batteries permitted, and under what conditions? Yes — the City's own Building page describes Symbium's instant-permitting tool as covering 'residential solar and/or battery storage'; no LBMC-specific ESS conditions were found beyond that, and the full-text-read 2022 CFC local amendments contain no battery/ESS provision, so the unamended base 2022 CFC/CRC ESS rules govern. 65% · authority's own page + confirmed absence of local amendment
• Is there a separate ESS permit or inspection? No indication of a separate ESS permit/inspection — battery storage is folded into the same 'instant residential solar and/or battery storage permit' process as PV, per the Building page's own description. 55% · authority's own page
• Is a ground mount treated as a structure? Not established either way. LBMC Ch. 8-6 is titled and scoped to 'rooftop' solar only and never mentions ground-mounted arrays; Zoning Article 44 (Accessory Structures in R-1/R-2) sets generic setback/height/permit rules for accessory structures generally but never names solar arrays specifically. A ground-mounted PV array would most likely default to being treated as an accessory structure under Article 44 by ordinary interpretation, but no Los Banos document says so directly. 50% · absence confirmed by full-text read of two ordinance sources

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.

Nothing recorded for City of Los Banos on this step yet — 3 questions checked and found unpublished. The guidance above is general.

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? Delegated 72% · authority's own page
• If delegated, to whom? CSG Consultants, Inc. 72% · authority's own page (contact email) + authority's own procurement record (scanned PDF, OCR'd with tesseract)

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? Only one inspection is required and performed by the Building Department for small residential rooftop solar energy systems eligible for expedited review; it must be done in a timely manner and 'should include consolidated inspections.' 90% · authority's own ordinance
• Is a rough-in or mid-roof inspection required? No 85% · authority's own ordinance

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? No / not published 68% · confirmed absence (410 Gone response + no Wayback capture)
• Does the inspector verify labels and listings? Yes (inferred) 50% · inference from adopted code + standard inspection practice

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 (inferred) 50% · inference from standard SFR-retrofit permitting practice
• Who notifies the utility for PTO? Installer (or homeowner-applicant) 82% · utility tariff (PDF, text-layer, extracted with pdftotext)
• Is there a re-inspection fee? $100.00 (initial deposit, based on time & materials) 70% · fee schedule (dated 2019, city-labelled 'CURRENT')
• How are corrections issued and cleared? At the application stage, an incomplete submittal gets a written correction notice detailing all deficiencies, sent to the applicant for resubmission. At the field-inspection stage, a failed inspection authorizes a subsequent (re-)inspection. 82% · authority's own ordinance