City of Beverly Hills

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 page + municipal code
• What does this authority permit itself, and what does it delegate? Both 92% · municipal code definition
• Is a permit required for a residential rooftop PV system? Yes 97% · authority page + municipal code
• Is there a separate electrical permit, or is it combined? Combined 75% · permit application form
• Is a HOA or architectural approval required first? Yes in the Central Area and Trousdale Estates (both have a City Design Review process); No in the Hillside Area, which the City states explicitly has no design review process. In the Central Area, design review 'extends to any portion of a single-family residence that is visible from a public street' and covers aesthetic changes 'including but not limited to façade remodels, painting, window replacement, new roofing, etc.' — solar panels are not named specifically, so whether a street-visible rooftop array triggers it is inferred, not stated. 72% · authority page
• Is there a historic-district review? Yes, but only for properties that are designated City Landmarks or located within a City-designated Historic District (a narrow subset of parcels) — BHMC §10-3-3219 requires a Certificate of Appropriateness (COA) before a building permit for exterior work on such properties. The COA application does not name solar panels among its example triggers or exemptions (unlike West Hollywood's explicit solar exemption), so whether rooftop PV specifically requires a COA is inferred from the broad 'any change to the exterior of a landmark property' language, not stated outright. 65% · authority application form, dated
• Is a wind or windstorm certification required? No 65% · adopted fee schedule (absence)
• Is a Specific Use Permit or Council approval ever required? Not identified for standard residential rooftop PV — none of the three documented permitting pathways (SolarApp+, over-the-counter, electronic plan review) reference a Specific Use Permit, Conditional Use Permit, or City Council-level approval step. 60% · authority page (absence)
• Is there a system-size cap on residential generation? No hard generation cap found; the only size-based line is an eligibility gate, not a ceiling: residential systems 'under 10KW' may use the over-the-counter/walk-in review path, while larger residential systems and any system outside SolarApp+'s scope route to the electronic plan-review track instead of being prohibited. 85% · authority page

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 85% · authority page
• Must the contractor be registered with this authority before applying? No 55% · permitting handout (absence across 3 docs)
• Is a homeowner permitted to self-install and self-permit? Yes 90% · authority page

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? Plan Review and Permit Application form; two (2) sets of plans (or electronic upload via Project Dox for e-plan track); Contractor Authorization Letter (if application not signed by license holder); HOA Authorization Letter (if applicable); Property Owner Authorization Letter (if Architectural & Design Review applies); Structural Calculations; Title 24 energy compliance documentation; associated documentation as applicable. For ballasted PV specifically: SEAOC PV1-2012/PV2-2012 compliance documentation and an Engineer-of-Record load analysis. 88% · permitting handout
• How many copies, and in what format? Two (2) sets of plans for the walk-in/over-the-counter and appointment tracks; fully electronic upload to Project Dox for the e-plan review track; SolarApp+ Approval Document (PDF) uploaded through the Online Permit Application for the expedited track. 88% · permitting handout + authority page
• Is a site plan required, and what must it show? Yes — BHMC 9-1-108(B) requires construction documents to include 'a site plan showing the location of the proposed building and of every existing building on the property'; no solar-specific site-plan content list (e.g., a dedicated PV facility site plan) was found beyond this general requirement. 72% · municipal code
• Is a structural PE stamp required, and at what threshold? For ballasted (unattached) flat-roof PV arrays: an Engineer of Record must provide gravity/lateral load analysis (limited to +5% roof framing demand / +10% lateral system demand per 2023 [cited by the City as 'Los Angeles'] Existing Building Code §502.5/503.3), plus SEAOC PV1-2012 seismic and PV2-2012 wind compliance — this is a mandatory PE/SE stamp regardless of size. For standard rack-mounted/attached systems, 'Structural Calculations' is a required submittal item (Permitting Guide item 8) stamped when the Building Official determines it necessary under BHMC 9-1-108(A); no universal weight/size threshold is separately published. 80% · authority page + municipal code
• Is an electrical PE stamp required, and at what threshold? Solar photovoltaic systems are explicitly listed in the City's MEP Plan Review Thresholds document as always requiring electrical plan review, and per that document's cover paragraph, plans for such review 'must bear the seal and signature of a licensed electrical engineer, mechanical engineer, civil engineer, or architect as appropriate' — i.e., no minimum size threshold; all residential solar PV requires a stamped electrical plan set. 88% · department handout, dated (Rev. Mar 2024)

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? Three portals depending on track: the Online Permit Application (OPA, beverlyhills.org/opa) for applying/paying; Project Dox for uploading/reviewing plans on the electronic-plan-review track; CitySmart for scheduling inspections and payments. The SolarApp+ national platform (gosolarapp.org) is used for the expedited automated-review track before OPA submission. 90% · authority page
• Can the whole application be completed online? Yes, for the SolarApp+/OPA/Project Dox track — application, plan upload, fee payment, and inspection scheduling (CitySmart) can all be completed online. The over-the-counter track instead requires an in-person appointment or walk-in visit (Mon-Thu 8-10am) to submit and pay. 82% · authority page
• What does a residential solar permit cost? $450 flat for residential systems ≤15 kW, plus $15/kW for each kW above 15 kW (per Gov. Code §66015); a Permit Issuance Fee of $92 and a 3.7% Technology Fee surcharge apply on top per the same schedule. Note: applicants using the SolarApp+ track pay a separate SolarApp+ platform administrative fee (amount not published by the City) in addition to this permit fee. 90% · adopted fee schedule
• How is the fee calculated? Tiered (flat base fee + per-kW rate above a threshold) 90% · adopted fee schedule
• Is there a separate plan-check fee? No — the Solar Energy Fee line item in the current fee schedule appears to be a single all-in permit fee under the Gov. Code §66015 cap; it is not paired with a separate 'Plan Check Fee' line the way plumbing/electrical/mechanical trade fees are (those show an explicit 8.33% + $51-minimum plan-check line, which the Solar Energy Fee rows do not). 62% · adopted fee schedule (inference from table structure)

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? 3 weeks for the electronic plan-review track (re-submittals: 2 weeks) — 'Solar PV Systems' is explicitly listed under the 'Small Projects: 3 Weeks' category. The over-the-counter/walk-in track (residential systems under 10kW) is reviewed same-visit, in person. 92% · permitting handout, dated Jul 2025
• How long is an issued permit valid before it expires? 365 calendar days (1 year) from issuance if work has not commenced; if commenced, the permit expires 180 calendar days after the date of the last successful inspection. A one-time extension of up to 180 days may be granted on written request within 30 days of expiration. 95% · municipal code
• Which utility handles interconnection here? Southern California Edison (SCE) 95% · authority page
• Where does the utility sit in the sequence? After permit (inferred) 62% · municipal code (inference)

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% · municipal code
• Which building code edition is in force? 2025 California Building Code and 2025 California Residential Code, with Beverly Hills amendments (BHMC Title 9, Chapter 1, Articles 2/2A), effective January 1, 2026. 95% · authority FAQ, current + municipal code
• Which fire code edition is in force? 2025 California Fire Code, with Beverly Hills amendments (BHMC 9-2-1/9-2-2), including Appendices B, BB, C, CC, D, F, and H, effective January 1, 2026. 95% · municipal code
• Are there local amendments to any of the above? Yes 95% · municipal code
• What is the installation judged against? The 2025 California Building/Residential/Electrical/Fire Codes as locally amended by BHMC Title 9, plus the City's 2010 'Solar Photovoltaic Installation Guideline' (joint Fire Dept/Building & Safety document) for fire-access, marking and ground-mount rules, and SEAOC PV1-2012/PV2-2012 for ballasted-array structural design. 85% · municipal code + authority guideline

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? Per the City's 2010 Solar Photovoltaic Installation Guideline (still the current published standard, linked live from the 2026 Solar Panels page): hip-roof residences need one 3'-wide clear pathway from eave to ridge on each occupied slope; single-ridge residences need two 3'-wide pathways; modules must stay ≥1.5' from a hip/valley (0' if only one side is occupied); flat roofs need two 3'-wide pathways corner-to-corner plus a 3'-wide clear perimeter; modules may be no higher than 3' below the ridge; and residential (1-2 unit) arrays may not exceed 75' in any dimension. Commercial/3+-unit buildings have separate, larger clearances (4-6' perimeter, 150' max array dimension). 85% · authority guideline, dated 2010

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 is required under NEC Article 690.12, which is in force statewide via the 2025 California Electrical Code (based on the 2023 NEC), adopted by BHMC 9-1-301 without local amendment to Article 690. The City's own 2010 Solar Photovoltaic Installation Guideline predates 690.12 entirely (rapid shutdown did not exist in the NEC until 2014) and does not mention it at all — a clear vintage gap between the City's only dedicated solar handout and the code it is meant to implement. 70% · authority guideline (gap) + adopted code (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 2010 Guideline: (1) a marking at the main service disconnect reading 'CAUTION: SOLAR ELECTRIC SYSTEM CONNECTED'; (2) markings on all DC conduit/raceways/enclosures/cable assemblies/junction boxes reading 'CAUTION: SOLAR CIRCUIT', placed every 10 feet, at turns, and above/below penetrations; (3) the same marking format at inverters; (4) a marking at any battery-backup disconnect. 88% · authority guideline
• Does the authority specify placard wording of its own? Yes 90% · authority guideline
• Does it specify letter height, colour or material? Yes: red background, white lettering, minimum 3/8-inch letter height, all capital letters, Arial or similar non-bold font, reflective weather-resistant material (a durable adhesive label satisfies this); the standard cited for weather-rating is UL 969, though UL listing of the marking itself is not required. 92% · authority guideline
• Where must the labels be placed? At the main service disconnect (inside the panel, or on the outside cover if the disconnect operates with the panel closed, for residential); within 3 feet of the PV array or before the DC conduit enters the building; on DC conduit/raceways/enclosures every 10 feet, at turns, and above/below penetrations; at inverters; and within 3 feet of any battery-storage disconnect (which must also be accessible from the building exterior). 88% · authority guideline

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 (via the adopted Electrical Code, not a separate City-maintained approved-products list). BHMC 9-1-106 defines 'LISTED AND LISTING' by reference to nationally recognized testing/inspection agencies, and the 2010 Guideline requires marking materials to meet UL 969 weather-rating. 65% · municipal code (general listing requirement, not solar-specific list)
• Are batteries permitted, and under what conditions? Batteries/ESS are not given a dedicated local ordinance by Beverly Hills — the Fire Code local amendments (BHMC 9-2-2) were read in full and add no Chapter 12 (energy systems) provisions, so the base, unamended 2025 California Fire Code Chapter 12 governs ESS installation and clearances. The City's only battery-specific local text is the 2010 PV Guideline's requirement that a battery-backup system have its own disconnect within 3 feet of the storage components, accessible from the exterior and marked per the standard format. No dedicated ESS handout (of the kind Manhattan Beach or Foster City publish) was found. 68% · municipal code (confirmed absence) + authority guideline
• Is there a separate ESS permit or inspection? No — no distinct 'ESS permit' type was found; the MEP Plan Review Thresholds document lists 'storage battery' systems under the same Electrical plan-review threshold category as solar PV and standby generators, implying they are processed under the standard building/electrical permit rather than a separate permit track. 55% · department handout (inference)
• Is there a local rule on service upgrades or busbar sizing? No local rule found. BHMC 9-1-302 ('Amendments To California Electrical Code') was read in full and contains exactly one amendment — to CEC §701.1, a legally-required standby (generator) power system mandate for major single-family remodels/additions — with no provision addressing busbar sizing or service-panel upgrades for solar/PV interconnection specifically. 85% · municipal code (confirmed absence)
• Is a specific mounting system or attachment spacing required? For ballasted (unattached) flat-roof PV: mandatory SEAOC PV1-2012 (seismic, via prescriptive method, nonlinear response history, or shake-table test) and PV2-2012 (wind, via prescriptive pressure coefficient or wind-tunnel test) compliance, plus an ASTM G115 sliding-friction test and an Engineer-of-Record gravity/lateral load analysis. For standard rack-mounted/attached systems, no Beverly-Hills-specific attachment-spacing rule was found beyond the general structural-calculations submittal requirement. 78% · authority page

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 (CitySmart, up to 10 days in advance) or Phone (automated system at 310-285-2534/'BLDG'). Fire-specific rough/final inspections (beyond rough fire-alarm, which goes through the Building Inspector) must be booked directly with the BHFD Prevention Division at 310-281-2703, not through CitySmart. 92% · authority page + handout
• How much notice is required? BHMC 9-1-111(T) allows the building official to require inspection requests 'at least one business day' in advance. In practice, a limited number of next-day inspection slots open online each weekday at 9am on a first-come/first-served basis, and requests can be scheduled up to 10 days ahead. 88% · authority page + municipal code
• Are same-day or AM/PM windows offered? No AM/PM window system was found; the City instead offers a limited number of next-day slots (not same-day) released online at 9am each weekday, first-come/first-served. 75% · authority 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 92% · authority page
• If delegated, to whom? N/A — not delegated. Self-performed by the City of Beverly Hills Building & Safety Division (building/electrical) and the Beverly Hills Fire Department (fire). 88% · municipal code

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? General code order (BHMC 9-1-111): rough trades inspection (electrical/plumbing/mechanical, if concealed) before framing/concealment, then a final inspection after the work is complete. For a typical residential rooftop PV retrofit, the City's own three published process pages (SolarApp+, OTC, e-plan) each describe only a single post-issuance 'Inspection' step, implying most retrofits go straight to a final inspection unless conduit/wiring will be concealed. 65% · municipal code + authority page
• Is a rough-in or mid-roof inspection required? Conditional — a rough-in inspection is required under BHMC 9-1-111(E) only if wiring/conduit will be concealed (e.g., routed through an attic or wall) before covering; the City's solar-specific process pages describe only a single 'Inspection' step for typical rooftop retrofits, implying most jobs receive only a final. 62% · municipal code (inference)

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.

• What must be on site at inspection? Approved plans, the issued permit, and (per the general construction-documentation rule) Title 24 energy compliance reports and any other approved construction documents must be maintained on site at all times. 90% · authority handout, dated Jun 2024
• Does the inspector verify labels and listings? Yes (inferred) — no BH document states this explicitly for solar, but BHMC 9-1-111(U) requires the building official to confirm compliance with 'this code' (which includes the CEC listing requirement and the 2010 Guideline's mandatory placards) before issuing a successful inspection. 55% · municipal code (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 (a signed-off final inspection/permit card) — not a Certificate of Occupancy. BHMC 9-1-112 ties Certificate of Occupancy to new occupancy or a change in occupancy classification; a rooftop PV retrofit on an already-occupied single-family home does not trigger that process, only the standard 'Final Inspection... after the building is completed and ready for occupancy' under 9-1-111(P). 80% · municipal code (inference)
• Who notifies the utility for PTO? Installer (inferred) 50% · inference (utility practice, not a BH document)
• Is there a re-inspection fee? $289 90% · adopted fee schedule
• How are corrections issued and cleared? The building official notifies the permit holder in writing wherever work fails to comply (a correction notice); no further concealment is authorized until corrected work is re-inspected and approved. Work status is tracked via a permit/inspection card posted at the job site, and a reinspection fee applies if work is not ready or corrections are incomplete at the requested time. 78% · municipal code