City of Orinda

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% · department page
• What does this authority permit itself, and what does it delegate? Delegated 95% · department page
• Is a permit required for a residential rooftop PV system? Yes 96% · municipal code
• Is there a separate electrical permit, or is it combined? Combined 80% · fee schedule
• Is a HOA or architectural approval required first? No -- not required by the AHJ 55% · municipal code
• Is there a historic-district review? No -- not for a typical residential PV retrofit 55% · municipal code
• Is a wind or windstorm certification required? No 65% · municipal code
• Is a Specific Use Permit or Council approval ever required? No -- not typically for a standard rooftop PV retrofit 55% · municipal code
• Is there a system-size cap on residential generation? 10 kW AC nameplate (or 30 kW thermal) is the ceiling for eligibility under the City's ministerial/expedited 'small residential rooftop solar energy system' process; it must also be sited on a rooftop of a detached SFR or duplex and not exceed the zoning district's building height limit. This is a gate for the streamlined path (citing Gov. Code section 65850.5), not an absolute ban on larger systems, which would go through standard review. 95% · municipal code

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 75% · department page
• Must the contractor be registered with this authority before applying? No 55% · department page
• Is a homeowner permitted to self-install and self-permit? Yes 78% · department 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? Complete digital plan set: roof/site plan showing module and equipment locations, existing roof framing, single-line diagram tying the system into the house electrical panel and PG&E service, manufacturer installation/grounding instructions and spec sheets (modules, inverter, racking, batteries if any), plus the County's Residential PV Eligibility & Structural Checklist (and Structural Criteria worksheet if any item on it fails). 90% · published checklist
• How many copies, and in what format? Digital: one bookmarked, unsecured, multi-page PDF, min 11x17 landscape (24x36 for ground-mount/commercial roof), max 100MB, drawn to scale from drafting software (no scans), 3.5in x 6in blank column reserved for county stamps. Paper (in-office only): 3 sets, 11x17 minimum. 88% · published checklist
• Is a site plan required, and what must it show? Yes -- a roof plan (roof-mount) or site plan (ground-mount) showing module/array locations, existing roof framing, inverter/battery/equipment locations, plus a separate roof-access/pathway diagram showing disconnect and roof-access-point locations. 88% · published checklist
• Is a one-line / three-line diagram required? Yes 92% · published checklist
• Are string and conductor calculations required? Yes 75% · published checklist
• Is a structural PE stamp required, and at what threshold? Required only if the array fails the County's own 'Structural Criteria for Residential Flush-Mounted Solar Arrays' prescriptive checks (roof condition, anchor horizontal spacing per Table 1, wind-uplift/fastener check) -- if any item is checked NO, project-specific drawings and calculations stamped and signed by a California-licensed Civil or Structural Engineer must be attached. 85% · 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? Contra Costa County's ePermits Center (epermits.cccounty.us) for the building/electrical permit itself; Orinda's own 'Application Submittal Portal' for the (usually-waived) Planning step; SolarAPP+ offered as an optional software-driven pathway for qualifying residential rooftop PV. 90% · department page
• Can the whole application be completed online? Yes 85% · department page
• What does a residential solar permit cost? $272 flat for a residential PV system ≤15 kW AC ($86 Building Permit/Inspection + $86 Plan Check + $100 Electrical Review), plus $15/kW above 15 kW AC. Thermal systems: $258 flat ≤10 kWth ($86+$86+$86), plus $15/kWth above 10 kWth. 95% · fee schedule
• How is the fee calculated? Tiered / Per kW 90% · fee schedule
• Is there a separate plan-check fee? Yes 92% · 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? Initial completeness review: about 4-5 business days (county's 'Step 1: Initial Review'); full plan-review duration after that is not fixed and depends on project complexity and correction cycles. Orinda's optional SolarAPP+ pathway (where used) issues instantly on submittal but was not separately confirmed as active for Orinda specifically. 70% · department page
• How long is an issued permit valid before it expires? Approximately 365 days of inactivity, inferred 55% · fee schedule
• Which utility handles interconnection here? Pacific Gas & Electric (PG&E) 90% · department page
• Where does the utility sit in the sequence? Parallel, with Permission-to-Operate gated on the AHJ's final inspection clearance 75% · 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 (CEC) 90% · adopting ordinance
• Which building code edition is in force? 2025 California Building Code / 2025 California Residential Code 95% · adopting ordinance
• Which fire code edition is in force? City's own codified Fire Safety chapter (OMC 8.20.010) still names the 2022 California Fire Code (per Moraga-Orinda Fire District Ordinance 23-01, ratified by the City in 2023) -- but MOFD's own Ordinances & Resolutions page shows Ordinance 26-01, 'Adopting the 2025 edition of the California Fire Code ... and repealing Ordinance 23-01', posted around 16 Jan 2026. The City's codified fire chapter has not yet been updated to reflect MOFD's newer adoption -- a code-cycle lag between the city code and the fire district's actual current code. 80% · department page
• Are there local amendments to any of the above? Yes, generally -- but none found specific to solar/PV/rapid shutdown/busbar sizing. 88% · municipal code
• What is the installation judged against? The installation is judged against the adopted 2025 CBC/CRC/CEC/CALGreen (as locally amended, none of which touch solar specifically), Civil Code section 714 (Solar Rights Act, per OMC 15.60.020(E)(3)), Gov. Code section 65850.5, and Contra Costa County's own Residential PV Eligibility & Structural Checklist for the expedited path. 85% · municipal code

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? A specific ridge-setback distance is not codified locally (not found in OMC or the county checklist); the county's Fire Safety Requirements do require 'a diagram of the roof layout of all panels, modules, clear access pathways and approximate locations of electrical disconnecting means and roof access points' as part of every submittal, and roof-access points must avoid overhead obstructions and be at strong points of construction -- but no numeric ridge-setback figure is stated in any Orinda- or Contra Costa-side document found. 65% · 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? Rapid shutdown is required under NEC 690.12 as incorporated into the 2023 NEC / 2025 CEC statewide adoption; no Orinda- or MOFD-specific document was found that separately cites or amends section 690.12. 65% · 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.

• Is a site plan / facility map placard required, and what must it show? Yes -- a roof-layout diagram showing all panel/module locations, clear access pathways, and the approximate locations of electrical disconnecting means and roof access points is a required part of every submittal (this functions as the site/facility-map placard-equivalent document). 85% · published checklist
• Does the UTILITY specify placards beyond the AHJ's? Yes -- PG&E Rule 21 section H.1.d requires a 'Visible Disconnect' with open/closed position markings, lockable and reachable 24/7, and shown on the single-line diagram -- a utility-side signage requirement independent of the AHJ's. 80% · 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.

• Where must the AC disconnect be, relative to the meter? PG&E Rule 21 section H.1.d requires the AC disconnect be visible, lockable, reachable 24/7 and carry open/closed markings; no specific distance (e.g. '3 ft' or '10 ft') from the meter was found in any PG&E, Orinda or Contra Costa document reviewed -- PG&E's more detailed Greenbook meter-proximity specification (TD-7001M / TD-2306M) is access-gated to PG&E-affiliated users and could not be retrieved. 65% · utility tariff
• Must equipment be on a specific approved list? No dedicated city/county-approved equipment list found -- standard CEC-listed/UL-listed component requirements apply via the manufacturer spec-sheet submittal requirement. 55% · published checklist
• Are batteries permitted, and under what conditions? Yes -- batteries/ESS are permitted. Moraga-Orinda Fire District's current fee schedule prices a dedicated 'Energy Storage Systems' fire construction permit (PR14.1, $1,151/permit) and a 'UL 9540A Modification' fee (PR14.3, $627/project), confirming ESS is a recognized, permitted installation category with its own fire plan-review and inspection. 80% · fee schedule
• Is there a separate ESS permit or inspection? Yes -- MOFD prices Energy Storage Systems (PR14.1) as a fire construction permit distinct from Solar Photovoltaic Power Systems (PR14.2); each bundles 1 plan review, 1 resubmittal, 1 inspection and 1 reinspection under the 'FIRE CONSTRUCTION PERMITS' category. It is not clear from the fee schedule alone whether every residential rooftop PV job (as opposed to only ESS or larger/non-exempt installs) actually triggers a MOFD permit in practice, so this is reported at moderate confidence. 70% · fee schedule
• Is a ground mount treated as a structure? Likely yes, by inference -- Contra Costa County's own City & Agency Directory page lists 'ground mount solar systems' explicitly among the project types requiring Central Contra Costa Sanitary District review (alongside 'new structures', 'additions', 'retaining walls' and other structures needing excavation review), and the county's residential solar fee schedule prices roof-mount and ground-mount PV under the same line items without differentiating structural classification. Orinda's own zoning code has no PV-specific ground-mount provision; a ground rack would most likely be classified as an 'accessory structure' under OMC 17.4.22 (min. 50 ft setback from any street-frontage property line) by default, though this is inference, not an explicit statement. 65% · department page
• Is there a local rule on service upgrades or busbar sizing? No general local CEC amendment to busbar sizing exists (control-checked absence in OMC 15.12). But Contra Costa County's own expedited-eligibility checklist for residential PV requires the system be 'interconnected to a single-phase AC service panel of nominal 120/220 Vac with a bus bar rating of 200 A or less' as a condition of using the streamlined/expedited review path -- an eligibility ceiling, not a minimum, and the opposite direction from the Palm Springs-style '225A minimum' amendment seen elsewhere. 80% · published checklist
• Is a specific mounting system or attachment spacing required? Yes -- the County's 'Structural Criteria for Residential Flush-Mounted Solar Arrays' worksheet specifies: modules parallel to roof plane with a 2in-10in gap to the roof surface; array weight capped at 4 psf (PV) / 5 psf (thermal); array covering no more than half the total roof area; and a maximum-horizontal-anchor-spacing table (Table 1) that varies by roof slope (flat-6:12, 7:12-12:12, 13:12-24:12) and rafter spacing (16in/24in/32in o.c.), plus a wind-uplift/fastener check. 88% · 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 / Phone 90% · 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? Delegated 90% · department page
• If delegated, to whom? Contra Costa County Building Inspection Division (Department of Conservation and Development) for building/electrical; Moraga-Orinda Fire District for fire, where a MOFD fire construction permit applies. 90% · 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? Building/electrical final inspection by Contra Costa County (after plan-check approval and fee payment); where a MOFD fire construction permit applies (e.g. ESS, or any job MOFD classifies under its PR14 category), MOFD separately performs its own plan review and field inspection under its own 'FIRE CONSTRUCTION PERMITS' bundle (1 plan review, 1 resubmittal, 1 inspection, 1 reinspection). The precise sequencing between the county's and MOFD's inspections for a given job was not documented in any single source found. 70% · department page

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 -- the County's Residential PV Eligibility & Structural Checklist functions as the published pre-inspection/plan-review checklist; a separate dedicated 'field inspection checklist' distinct from this document was not found. 65% · published checklist
• What must be on site at inspection? Approved, stamped plan set (matching what was submitted/approved), the completed and initialed Eligibility Checklist, and manufacturer spec sheets for major components -- inferred from the county's own submittal and review-process description rather than an explicit 'bring these documents to inspection' instruction. 50% · department page
• Does the inspector verify labels and listings? Yes 80% · published 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 (building-permit final inspection sign-off / approval to operate the system) -- no separate Certificate of Occupancy is issued for a residential PV retrofit; OMC 15.60.020(D) independently bars operating the system 'unless the City Building Official verifies in writing that it complies with the building permit,' which in practice is performed by the County on the City's behalf. 70% · municipal code
• Who notifies the utility for PTO? Installer 70% · utility tariff
• Is there a re-inspection fee? $150 per inspection trip (current Contra Costa County Land Development Fee Schedule, general reinspection line, applicable to building/electrical). Note: the county's own PV Eligibility Checklist (dated Nov 2015, still the live linked document) separately warns of a stale $100 re-inspection fee tied specifically to non-compliant plan formatting at the field-inspection stage -- both figures are reported since both documents are currently live. 85% · fee schedule
• How are corrections issued and cleared? Corrections are communicated by the plan reviewer by email or phone during the plan-review step; applicants may authorize the reviewer to make minor red-line corrections directly on plans without further contact (per the Eligibility Checklist's initialed authorization clause). No formal written-notice-and-response timeline was found. 70% · department page