Mendocino County

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, for the unincorporated area of Mendocino County. By delegation the County Building Division ALSO issues building/electrical permits for the incorporated cities of Fort Bragg and Point Arena. It is NOT the AHJ for Ukiah or Willits, which are separate incorporated cities with their own building departments. 90% · department page
• What does this authority permit itself, and what does it delegate? Both (Building and Electrical) -- the Building Division administers and issues a single building permit that covers structural, electrical (CEC), fire and energy review for residential PV; it does not delegate solar plan review or inspection to a separate agency, though four fire districts (Anderson Valley, Fort Bragg, Hopland, Little Lake/Willits, Ukiah) have review/approval authority alongside the County on new construction. 80% · department handout (PV Toolkit Doc #1, undated 2015 template, still linked from current site)
• Is a permit required for a residential rooftop PV system? Yes -- a Building Permit is required for a residential rooftop PV system; the County's own Building Permit Application form has a dedicated 'Photovoltaic' project-type checkbox. 95% · department handout
• Is there a separate electrical permit, or is it combined? Combined -- one Building Permit covers the structural and electrical (CEC 690/705) scope for a residential PV install; there is no separate stand-alone 'electrical permit' issued for the PV work itself. 75% · adopted department policy (Building Policy #14, effective 13 Mar 2026)
• Is a HOA or architectural approval required first? No -- the County does not require HOA or architectural approval as part of its own building permit process. 55% · published checklist
• Is there a historic-district review? No, for eligible systems -- Ordinance No. 4530 (adopted 19 Dec 2023) exempts eligible roof-mounted solar energy systems from 'all discretionary review' and from 'review by the Planning Division' in the Coastal Zone, which is where the County's Historic Review Board (Town of Mendocino) sits. 70% · department fact sheet, citing Ord. No. 4530 (19 Dec 2023)
• Is a wind or windstorm certification required? No -- no windstorm/wind-zone certification requirement found (unlike Texas TDI-style programs). 60% · department handout (Structural Criteria, wind-uplift covered by anchor-spacing tables instead)
• Is a Specific Use Permit or Council approval ever required? No, for qualifying systems -- 'Planning review IS NOT required for solar PV installations of this size' (<=10kW rooftop); Ordinance 4530 separately exempts eligible rooftop solar from discretionary Coastal Zone review. Larger/non-qualifying or ground-mount systems outside the expedited program could in principle require a use permit under general zoning, but no such case is documented. 75% · department handout
• Is there a system-size cap on residential generation? No hard cap found on residential system size; 10kW AC is only the eligibility threshold for the expedited/over-the-counter review track -- larger systems go through standard (non-expedited) plan review rather than being prohibited. 65% · department handout (Eligibility 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 -- an owner-builder (property owner) or a California-licensed, bonded contractor (or an authorized agent of either) may pull the permit. 90% · department page
• Must the contractor be registered with this authority before applying? No separate County contractor-registration step found beyond standard CSLB licensing. 55% · published checklist
• Is a homeowner permitted to self-install and self-permit? Yes -- the Building Division explicitly accepts applications from the property owner as an owner-builder for self-install/self-permit. 90% · 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? Completed Eligibility Checklist; electrical plan or the Standard Electrical Plan (PV Toolkit Doc #3 or #4); roof/site plan showing panel layout, fire classification, access pathways and label locations; Structural Criteria (PV Toolkit Doc #5) or full engineer-stamped structural drawings if the project fails the criteria checklist; completed permit application. 90% · department handout
• How many copies, and in what format? Over-the-counter: 1 completed permit application + 1 copy of an 8.5x11 plot/site plan. Non-OTC ('Other') projects: 3 copies of construction plans (printed or digital PDF), plus 2 copies each of Title 24 energy compliance and wet-stamped engineering calcs where applicable. 85% · published checklist
• Is a site plan required, and what must it show? Yes -- a site/roof plan is required showing: panel/module layout, north arrow, lot dimensions, distance from property lines to structures, PV fire classification, code-compliant access pathways, and locations of all required labels/disconnects. 90% · department handout
• Is a one-line / three-line diagram required? Yes -- a one-line electrical diagram of the complete system is required. 95% · adopted department policy
• Are string and conductor calculations required? Yes -- module string counts, conductor type/size, conduit type/size and conductor counts per conduit run must be specified. 80% · adopted department policy
• Is a structural PE stamp required, and at what threshold? Rooftop: a California-licensed structural/civil engineer's stamp is required only for systems that fail the Structural Criteria checklist (e.g., >4 psf array weight, roof covers >50% of area, anchor spacing exceeds Table 1, more than one roof covering, non-zero snow load, or Wind Exposure D/hillside/near-ocean siting). Ground-mount: an engineer's stamp is required whenever the array exceeds 7 feet in height. 90% · department handout (PV Toolkit Doc #5)
• Is an electrical PE stamp required, and at what threshold? No separate electrical-PE-stamp threshold identified; non-standard electrical plans need only be prepared and signed by the installing C-10 contractor or a CA-licensed electrical contractor/engineer for large services (>200A), not a mandatory electrical PE stamp for PV itself. 60% · adopted department policy (Building Policy #2, eff. 10 Mar 2026)

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? e-TRAKiT (etrakit.mendocinocounty.org) 95% · portal landing page
• Can the whole application be completed online? Largely yes -- applications, including PV, can be submitted electronically via e-TRAKiT and approved 'over the counter electronically,' and the County publishes a 'Guidelines for Online Permit Applications' handout, though that handout's full text could not be retrieved to confirm whether payment and inspection scheduling are fully self-service. 60% · department handout
• What does a residential solar permit cost? Approximately $83 minimum, capped at $500 total, based on project valuation (per the department's own 2015 PV Toolkit handout); a newer, undated County handout for the same expedited program states only 'Fees: To be in compliance with CA State AB 1414' without restating a dollar figure. 55% · department handout (dated 2015, still linked live)
• How is the fee calculated? Valuation-based (project cost), with square footage used for some structure types; per the Board of Supervisors' annually-adopted Master Fee Schedule. 70% · department procedure (image-only PDF, OCR'd)
• Is there a separate plan-check fee? Yes -- a distinct Plan Check fee line exists separate from the Basic Construction fee. 80% · department procedure (image-only PDF, OCR'd)

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? Eligible/expedited rooftop PV (<=10kW, meeting the Eligibility Checklist): over-the-counter same day when staff is available, otherwise 1-3 business days. Non-expedited/standard building permits generally: 6-8 weeks plancheck. 85% · department handout
• How long is an issued permit valid before it expires? Issued building permits (non-Class K) are valid 1 year from issuance; each approved inspection extends validity another 365 days; Class K permits are valid 3 years. 80% · adopted department policy (Building Policy #9, eff. 13 Mar 2026)
• Which utility handles interconnection here? PG&E (Pacific Gas and Electric Company). Sonoma Clean Power (SCP) operates as a Community Choice Aggregator layered on PG&E's wires in parts of the county -- SCP is a generation-service provider, NOT the interconnecting/wires utility. 75% · county page
• Where does the utility sit in the sequence? After permit -- PG&E interconnection/PTO ('activation') occurs after the County's final building inspection and approval. 65% · department handout

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? California Electrical Code (statewide, based on the 2023 NEC as part of the 2025 Title 24 cycle, effective 1 Jan 2026). Mendocino's current Building Policy #14 (13 Mar 2026) cites 'California Electrical Code (CEC), including Sections 690 and 705' without stating the numeric cycle. 60% · adopted department policy
• Which building code edition is in force? California Building Code and California Residential Code, 2025 edition (Title 24 Parts 2 & 2.5, statewide, effective 1 Jan 2026). Policy #14 cites 'CBC Chapter 15' and 'CRC Sections R329 & R330.' 60% · adopted department policy
• Which fire code edition is in force? California Fire Code (2025 edition, Title 24 Part 9, statewide) plus the California Wildland-Urban Interface Code -- both cited by name in current Building Policies #5 and #14 (Mar 2026). 60% · adopted department policy (Building Policy #5, eff. 10 Mar 2026)
• Are there local amendments to any of the above? Yes -- the County layers its own Building Policies (numbered #1-#19) on top of the state codes, e.g. the 7-foot ground-mount PE-stamp trigger, structural-criteria pass/fail tables, and the 100A/200A electrical-service rules in Policy #2, none of which are simple restatements of CBC/CEC text. 60% · adopted department policy
• What is the installation judged against? The current California Building Code, Residential Code, Electrical Code and Fire Code as locally amended, plus County of Mendocino Building Policies #1/#2/#5/#14 and the PV Toolkit standard plans. 85% · adopted department policy

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? Access pathways are referenced to California Residential Code Section 324 (per the County's own Expedited Rooftop PV handout); the roof plan must show fire classification and code-compliant access pathway locations. Exact ridge-setback dimensions themselves live in the ICC-copyrighted CRC/CFC tables and are not independently republished in any County document found. 65% · department handout

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 as a function of the statewide California Electrical Code (CEC 690.12), which Mendocino enforces as adopted; County documents cite 'CEC Sections 690 and 705' generally but do not separately quote 690.12 by number. 55% · adopted department policy

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? At minimum: (1) sign identifying PV power-source system attributes at the DC disconnect, (2) sign identifying the AC point of connection, (3) sign identifying the switch for the alternative power system. The utility (PG&E) separately requires its own 'UTILITY AC DISCONNECT SWITCH' label at its disconnect (see q42). 90% · adopted department policy
• Does the authority specify placard wording of its own? Partially -- the County specifies what each required sign must identify (DC disconnect attributes, AC point of connection, alternate power switch) but does not mandate verbatim wording of its own the way PG&E does for its utility disconnect label. 70% · adopted department policy
• Does it specify letter height, colour or material? The County's PV Toolkit standard-plan document recommends (per ANSI Z535.4 guidance) a phenolic plaque with contrasting text/background colors and 'no type size specified, but 20-point (3/8") should be considered the minimum' -- framed as guidance, not a hard county mandate. PG&E separately mandates a hard minimum of 3/8" all-capital lettering, engraved phenolic or ANSI Z535.4-compliant, for its own utility disconnect label (utility-level, not AHJ). 70% · department handout (PV Toolkit Doc #4)
• Is a site plan / facility map placard required, and what must it show? Yes -- a roof/site plan (facility-map equivalent) is required showing panel/module layout, north arrow, lot dimensions, distance to property lines/structures, PV fire classification, clear access pathways, and locations of all required labels/markings and electrical disconnects/roof access points. 80% · department handout
• Does the UTILITY specify placards beyond the AHJ's? Yes -- PG&E's own Distribution Interconnection Handbook document (Greenbook doc 060559, 'Disconnect Switch Requirements for Distributed Generation Customers,' Rev. #07, approved 25 Mar 2022) requires a permanently attached label reading e.g. 'UTILITY AC DISCONNECT SWITCH,' engraved phenolic or ANSI Z535.4-compliant, minimum 3/8" all-capital lettering -- beyond and in addition to the AHJ's own three signs (q38). 90% · utility interconnection handbook (PG&E Greenbook doc 060559, Rev. #07, 3/25/2022)
• Where must the labels be placed? AHJ level: at the DC disconnect, at the AC point of connection, and at the alternate-power-system switch. Utility (PG&E) level: the AC disconnect label must be on the front of the switch, and the switch itself must be within 10 feet and in line of sight of PG&E's meter, at the same grade level as the meter, mounted 48"-75" high if wall/pad-mounted, and never on a roof or a floor above grade; a location map is required if the disconnect is not co-located with the meter. 85% · utility interconnection handbook + department policy

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? Within 10 feet, in line of sight, of PG&E's electric meter; at the same grade level as the meter if outdoors; mounted 48"-75" high if wall- or pad-mounted; never on a roof, an upper floor, or inside a non-approved meter room. 95% · utility interconnection handbook
• Must equipment be on a specific approved list? Yes -- equipment must be listed/labeled for its PV application per CEC 690.4(D) (equipment cut sheets for inverters, modules, disconnects and combiner boxes are a required submittal item); this is the statewide CEC listing requirement rather than a County-specific approved-products list. 80% · department handout
• Are batteries permitted, and under what conditions? Yes, with conditions -- battery storage disqualifies a project from the expedited/over-the-counter PV track (the Eligibility Checklist requires the system be 'utility interactive and without battery storage' to qualify), but batteries are explicitly accommodated in the standard (non-expedited) submittal: they must be shown on the electrical diagram with their location and venting called out. 85% · department handout (Eligibility Checklist)
• Is there a separate ESS permit or inspection? No standalone 'ESS permit' identified -- battery/ESS installation appears to be folded into the standard Building Permit/inspection process described in Policy #14, not a separately named permit type. 55% · adopted department policy
• Is a ground mount treated as a structure? Yes -- a ground-mounted PV system is treated as a structure requiring foundation/footing plans and reinforcement details, with a California-licensed engineer's approval mandatory for arrays exceeding 7 feet in height. 90% · adopted department policy
• Is there a local rule on service upgrades or busbar sizing? Yes -- Building Policy #2: a single-family residence must have a minimum 100A, 3-wire service (CEC 230.79(c)); an over-the-counter panel-replacement permit is allowed only for same-amperage replacement on an already-permitted structure; any new panel over 200A requires load calculations and line drawings from a CA-licensed electrical contractor or engineer; amperage must be justified from existing loads only, not projected/future loads. 90% · adopted department policy
• Is a specific mounting system or attachment spacing required? Yes -- prescriptive anchor/attachment spacing tables (Structural Criteria, PV Toolkit Doc #5): e.g. up to 6'-0" horizontal anchor spacing at 24" rafter/truss spacing on flat-to-6:12 roofs, tightening to as little as 1'-4" on steep slopes; expedited-program truss rule requires 6' spacing generally, or 4' alternating spacing if truss spacing is 16" o.c. or splice locations near rail attachments cannot be confirmed. 90% · department handout (PV Toolkit Doc #5)

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 (automated inspection request line, separate Ukiah/Fort Bragg numbers) or Portal (e-TRAKiT online scheduling). 90% · department page
• How much notice is required? By 3:00 PM the business day before the requested inspection (effectively 1 business day's notice). 90% · department page
• Are same-day or AM/PM windows offered? AM/PM windows are attempted but not guaranteed -- the department tries to meet morning or afternoon requests, verifiable by calling between 8:00-9:00 AM the day of inspection. 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 -- the County Building Division performs its own final solar inspections for the unincorporated area, Fort Bragg and Point Arena. 90% · department page
• If delegated, to whom? Not delegated -- self-performed by the County Building Division's own inspectors within its jurisdiction (unincorporated area, Fort Bragg, Point Arena). Ukiah and Willits perform their own inspections independently and are not part of this delegation. 85% · 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? At minimum a final inspection is required before activation. Ground-mount or larger installs also require a foundation/footing inspection (checked per Policy #14 Section 4.1) prior to final; re-roof work involving new plywood sheathing requires a roof-sheathing nailing inspection before the sheathing is covered. 70% · adopted department policy
• Is a rough-in or mid-roof inspection required? Yes, in specific cases -- a roof-sheathing nailing inspection is required before covering new plywood sheathing (re-roof/reframe scenarios), and a foundation/footing inspection is required for ground-mount arrays; a simple rack-only rooftop retrofit with no new sheathing does not appear to require a distinct rough-in stage beyond final. 55% · adopted department policy

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 -- inspection checklists are embedded directly in the PV Toolkit Application Guide, the Ground Mount Policy and Building Policy #14; a standalone 'Checklist for FINAL Inspection' PDF is also listed on the Building Division's forms page, though its full text could not be retrieved (not archived by Wayback under any document ID found; live site 403s). 75% · department handout
• What must be on site at inspection? The approved job-copy plans and the permit itself must be on site for the inspector to review, and the property address must be posted in numbers 2.5"-4" high, visible from the road. 90% · department page
• Does the inspector verify labels and listings? Yes -- the inspector explicitly verifies module/inverter make-model against plans and spec sheets, equipment listing/labeling, and that installed signage matches equipment ratings (inverter voltage rating vs. sign, OCPD ratings vs. sign, etc.). 90% · adopted department policy

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 (final inspection approval / 'activation'), rather than a certificate of occupancy, green tag, or letter. 80% · department handout
• Who notifies the utility for PTO? Installer -- consistent with standard California net-metering practice, the installer/customer submits the interconnection/PTO paperwork to PG&E once the County has granted final approval; this is not explicitly spelled out by Mendocino County itself. 55% · department handout
• How are corrections issued and cleared? Corrections are issued via a written correction/revision notice from plan review or the field inspector; the applicant submits a completed Revision/Recheck form plus a cover/correction letter describing the changes. The permit status is changed to REVISION while under review, no inspections occur on the revised area until the revision is approved, and required plan revisions must be approved before work resumes. 80% · adopted department policy