City of Redondo Beach

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 permit page
• What does this authority permit itself, and what does it delegate? Both 90% · authority department page
• Is a permit required for a residential rooftop PV system? Yes 98% · authority permit page
• Is there a separate electrical permit, or is it combined? Separate 80% · authority permit page
• Is a HOA or architectural approval required first? No 70% · authority checklist (absence)
• Is there a historic-district review? No general requirement found for non-landmarked properties; Historic Preservation review applies only to designated landmark structures/districts, and no solar-specific interaction with that program is documented. 55% · authority department page
• Is a wind or windstorm certification required? No 70% · authority checklist (absence)
• Is there a system-size cap on residential generation? No hard maximum on residential generation size, but there are procedural thresholds: systems ≤10kW AC that are roof-mounted, utility-interactive and without battery storage qualify for the expedited/Standard-Plan review; systems ≤15kW AC (or ESS ≤1 unit/20kWh) qualify for SolarAPP+ automated review; anything larger or with a larger ESS must go through full standard plan review rather than being capped outright. 80% · authority checklist

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

• Who is allowed to pull the electrical permit? Either 50% · authority FAQ
• Must the contractor be registered with this authority before applying? Yes 90% · authority FAQ
• Is a homeowner permitted to self-install and self-permit? Not directly addressed for the standard track; No for the SolarAPP+ track 55% · authority FAQ

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? Completed permit application; compliance with the Eligibility Checklist for Expedited Solar PV Permitting; a Standard Electrical Plan (central/string or microinverter) OR a full electrical plan (service/utility disconnect location, module/string counts, inverter make/model, one-line diagram, grounding/bonding, battery locations if any, equipment cut sheets, CEC 690/705 labeling); a roof plan showing roof access point, code-compliant access pathways, fire classification and label locations; and a completed Structural Criteria form (or PE-stamped structural calcs if the criteria form fails). 95% · authority permit page
• How many copies, and in what format? Digital submission only, via the iWorQ Citizen Portal, PDF format, named per the city's file-naming convention (e.g. 'PC1_COMPLETE_PLANS', 'PC1_STRUC_CALCS', 'PC1_ENERGY_CALCS') 80% · authority checklist
• Is a site plan required, and what must it show? Yes — site diagram showing arrangement of panels on roof or ground, north arrow, lot dimensions, and distance from property lines to adjacent buildings/structures (existing and proposed) 95% · authority permit page
• Is a one-line / three-line diagram required? Yes 95% · authority permit page
• Are string and conductor calculations required? Yes 90% · authority permit page
• Is a structural PE stamp required, and at what threshold? Yes, but only if the system fails the expedited Structural Criteria checklist (roof slope 0–26°, single roof with no reroof overlay, 2–10in module standoff, ≤4 psf PV / 5 psf thermal, array ≤50% of roof area, lag-screw anchors per the standard spacing table). If any item fails, project-specific structural drawings/calculations stamped and signed by a California-licensed Civil or Structural Engineer are required. 95% · authority checklist
• Is an electrical PE stamp required, and at what threshold? Not required for systems meeting the Standard Plan / Eligibility Checklist; no separate electrical PE-stamp requirement is mentioned anywhere in the solar submittal materials (only structural stamps are called out). 60% · authority permit page

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? iWorQ ('Citizen Portal') — https://redondobeachca.portal.iworq.net/portalhome/redondobeachca — launched 31 Mar 2025 for all Planning/Building applications, replacing the prior system. 90% · authority permit page
• Can the whole application be completed online? Yes 90% · authority permit page
• What does a residential solar permit cost? $362.00 flat (Electrical permit, 'Solar-Photovoltaic - Residential'), per the FY26-27 Community Development Master Fee Schedule effective 15 Aug 2026 (Resolution CC-2606-044). Note: the standalone Solar Photovoltaic Permits webpage separately states a combined 'plan review and permit fee not to exceed $500.00' — the two documents are not reconciled. 90% · fee schedule
• How is the fee calculated? Flat 90% · fee schedule
• Is there a separate plan-check fee? No separate mandatory plan-check fee for a standard/eligible system — the $362 fee is a combined electrical permit fee. If additional plan review is needed (e.g., non-eligible/oversized systems or plan revisions), it is billed at the general 'Stand Alone Plan Check' hourly rate of $275/hr. 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? SolarAPP+ path: instant permit issuance once fees are paid and documents uploaded. Manual/standard plan-review path: no published turnaround time found. 55% · authority permit page
• Which utility handles interconnection here? Southern California Edison (SCE) 85% · authority department page

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 (per the city's current 'Building Ordinances and Codes' page referencing 'the 2025 California Building Codes, which Redondo Beach adopts in part'). CONTRADICTION FLAGGED: several of the city's own solar-specific documents are dated to older cycles — the Residential Construction Checklist (rev. 01.19.23) says 'This project shall comply with the 2022 edition of the California... Electrical Code', and the Solar Inspection Guide references '2016 versions unless otherwise noted' of CEC/CRC/CBC/CFC. The eCode360 legislative history shows amendments only through Ord. No. 3294-25 (10 Jun 2025), which predates the typical 1 Jan 2026 effective date of a 2025-cycle adoption ordinance. 60% · authority department page
• Which building code edition is in force? 2025 California Building Code (per city's current code page), with the same dating contradiction as Q29 — the Residential Construction Checklist (rev. 01.19.23) still cites 'the 2022 edition of the California Building Code.' 60% · authority department page
• Which fire code edition is in force? 2022 California Fire Code as locally amended by Ordinance No. 3247-22 (Title 3, Chapter 4, Article 1, §3-4.110), specifically Chapter 12 'Energy System' §§1205.2.1–1205.2.1.3 and §1207.11.3–1207.11.7. The city's own solar/ESS bulletin implementing this amendment is headed 'Effective: January 1, 2025' and was last verified/uploaded 19 Mar 2026, but still uses 2022-cycle CFC chapter/section numbers rather than any 2025-cycle renumbering. 65% · adopting ordinance / city bulletin
• Are there local amendments to any of the above? Yes 95% · adopting ordinance / city bulletin
• What is the installation judged against? California Electrical Code Article 690/705, California Residential Code R331, California Building Code Chapter 15 (1509.7), and California Fire Code §605.11 / Chapter 12 (1205/1207) as locally amended by Ordinance No. 3247-22 and IB-0223. 90% · authority checklist

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

• What ridge setback and access pathways are required? Ridge: panels/modules on one side of any ridge only, set back at least 3ft from the ridge; if panels are on both sides of the ridge, 5ft setback on one side and 3ft on the other. Flat/alternate roofs: minimum 3ft clear perimeter around roof edges. Access pathways (per the Inspection Guide, citing CFC 605.11.3.2/CRC R331.4.2): hip roofs need a 3ft-wide pathway eave-to-ridge on each panelled slope; hips/valleys need panels ≥18in from the hip/valley if on both sides; single ridges need two 3ft-wide pathways eave-to-ridge; panels may not sit closer than 3ft to the top of the ridge. 95% · adopting ordinance / city bulletin

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? Rapid shutdown (CEC 690.12) is not named explicitly in any Redondo Beach solar document reviewed, but is implicitly in force as part of whichever CEC edition applies (city's Inspection Guide cites the neighbouring CEC 690.11 arc-fault and 690.13–690.15/690.35 disconnect provisions but does not spell out 690.12 by name or edition). 55% · authority checklist

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

• Which placards does this authority require at the service equipment? WARNING: ELECTRIC SHOCK HAZARD (ground-fault, on inverter/battery enclosure, CEC 690.5(C)); WARNING: ELECTRIC SHOCK HAZARD — ungrounded DC conductors (CEC 690.35(F)); DC disconnect location marking (CEC 690.14(C)(1)); PHOTOVOLTAIC SYSTEM DISCONNECT (CEC 690.14(C)(2)); DC disconnect ratings placard (CEC 690.53); AC output/voltage placard at point of interconnection (CEC 690.54); service/PV disconnect directory (CEC 690.56(B)/705.10); shock-hazard/energized-terminals placard on DC disconnects (CEC 690.17); inverter-output-OCPD warning (CEC 705.12(D)(7)); and a red-background/white-letter 'WARNING: PHOTOVOLTAIC POWER SOURCE' placard on conduits/raceways/enclosures (CFC 605.11.1.4/CEC 690.31(E)(3)-(4)/CRC R331.2.4). 95% · authority checklist
• Does the authority specify placard wording of its own? Yes 95% · authority checklist
• Does it specify letter height, colour or material? Yes — the CFC 605.11.1.1/605.11.1.2 placard must have 3/8-inch (9.5mm) minimum white letters on a red background, made of reflective, weather-resistant material. 95% · authority checklist
• Is a site plan / facility map placard required, and what must it show? Yes — a directory/placard at the electrical service (and at the PV inverter if in a different location) showing the location of the service disconnecting means and the PV system disconnecting means, per CEC 690.56(B)/690.14(D)(4) and NEC 705.10. 90% · authority checklist
• Where must the labels be placed? Adjacent to the main service disconnect (visible from where the disconnect is operated); on all interior/exterior DC conduit, enclosures, raceways, cable assemblies, junction/combiner boxes and disconnects; and repeated every 10 feet, within 1 foot of turns/bends, and within 1 foot above/below roof or wall penetrations. 95% · authority 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.

• Must equipment be on a specific approved list? Yes (functionally) — PV modules must be listed to UL 1703 (AC modules also UL 1741), combiner boxes listed to UL 1741, inverters listed to UL 1741 and marked 'utility interactive', and all connectors/terminals/disconnects must be listed for their application; equipment must match the approved plans. 90% · authority checklist
• Are batteries permitted, and under what conditions? Yes, with conditions — ESS is permitted only in detached garages/detached accessory structures, or outdoors/on exterior walls at least 3ft from doors/windows entering the dwelling unit; ESS may NOT be installed in any structure attached to the dwelling unit. Individual ESS units are capped at 20kWh; aggregate rating is capped at 80kWh (in detached garages/accessory structures, on exterior walls, or outdoors on the ground). Installations exceeding those caps must comply with the full, non-amended CFC §§1207.1–1207.9. 95% · adopting ordinance / city bulletin
• Is there a separate ESS permit or inspection? Functionally yes — the Eligibility Checklist for the expedited/Standard-Plan residential PV path explicitly requires the system to be 'without battery storage'; any system with an ESS is automatically routed out of that fast-track review and into the standard/full plan-review process, and is separately governed by the Ordinance No. 3247-22 ESS location/rating rules. This is a functional separate review track rather than a distinct 'permit type' in the fee schedule (no separate ESS fee line item was found). 65% · authority checklist
• Is there a local rule on service upgrades or busbar sizing? Yes — for the expedited/Standard-Plan path, the PV system must interconnect to a single-phase AC service panel of nominal 120/220 VAC with a busbar rating of 225A or less, and be connected to the load side of the utility distribution equipment. IB-0223 also documents a local RBMC amendment to CEC §230.70(A)(1) requiring the service disconnecting means at a readily-accessible outside location (interior allowed only where approved by the Building Official). 90% · authority checklist
• Is a specific mounting system or attachment spacing required? Yes — prescriptive lag-screw anchor spacing (5/16in dia., 2.5in embedment, 4–6ft o.c. for rafters, 4ft o.c. staggered for trusses), 2–10in standoff gap between module and roof, ≤4 psf (PV) / 5 psf (thermal) loading, and array coverage ≤50% of total roof area, per the city's Structural Criteria form — used unless the manufacturer's own listed racking system documentation is submitted instead. 95% · authority 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 90% · authority permit page
• How much notice is required? Approximately 1 business day 85% · authority permit page
• Are same-day or AM/PM windows offered? No 85% · authority FAQ

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% · authority department page
• If delegated, to whom? N/A — not delegated 90% · authority 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? Primarily a single, comprehensive final electrical/solar inspection covering structural mounting, roof penetrations, conductor/conduit routing, grounding/bonding, equipment listing, labeling and access pathways — the city's Inspection Guide is structured as one 'Field Inspection Guide' rather than describing sequential rough-in/final stages. 80% · authority checklist
• Is a rough-in or mid-roof inspection required? No 65% · authority checklist (absence)

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 95% · authority checklist
• What must be on site at inspection? The city-issued permit (and, for SolarAPP+ projects, the SolarAPP+-generated inspection checklist/approval documents) must be on site; approved plans are implicitly required per standard practice since the inspector verifies work 'according to the approved plan' throughout the Inspection Guide. 85% · authority permit page
• Does the inspector verify labels and listings? Yes 95% · authority checklist

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 (permit finaled/closed in the iWorQ portal) 55% · authority permit page (inference)
• Is there a re-inspection fee? $174.00 flat 70% · fee schedule