Plumas 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, but only for UNINCORPORATED Plumas County. The one incorporated city, City of Portola, is a separate AHJ with its own in-house Building Department. 92% · codified ordinance + city department page
• What does this authority permit itself, and what does it delegate? Both — Plumas County's own Building Department (in-house; all staff on @countyofplumas.com, no contract-firm domain found) issues and inspects both building and electrical permits for unincorporated-area residential solar. Fire-code (CFC) adoption and R-3/WUI enforcement is ALSO assigned by ordinance to the Building Official (§8-1.09) — not to a separate county fire office (there is none). Actual fire suppression/dispatch response, however, is provided by whichever of 20 separate local fire protection districts/departments covers the parcel (no county fire department exists at all). 88% · department staff directory
• Is a permit required for a residential rooftop PV system? Yes. 96% · department handout
• Is there a separate electrical permit, or is it combined? Combined — Plumas County processes residential PV as a single permit (billed as an 'Electrical' fee line with a plan-review component covering the structural/roof review too), applied for on the county's Miscellaneous Building Permit Application, which lists electrical, structural repair, mechanical etc. as one form. No separate 'building permit' fee line exists alongside the PV electrical fee line. 76% · fee schedule / application form
• Is a HOA or architectural approval required first? Not a county-imposed requirement — the county's own PV documents mention only Planning/Zoning items (accessory-structure standards, setbacks, height, reflectivity) for freestanding units, with no HOA/architectural-review step in the county's own permitting process. (This does not mean an individual subdivision's private CC&Rs cannot impose one — that is outside the county's control and the Solar Rights Act, Civil Code §714, would apply.) 68% · department handout
• Is there a historic-district review? No historic-district review found — a full walk of the Title 9 (Planning and Zoning) chapter list found no historic-preservation or historic-district chapter at all (Chapters 1 General Plan, 2 Zoning, 3 Subdivisions, 4 Development Standards, 5 Mine/Reclamation, 6 Open Ranges, 7 Development Agreements, 8 Street Addresses, 9/9.5 Fire Safe/FHSZ, 10 Impact Fees, 11 Easements). 80% · codified ordinance (TOC)
• Is a wind or windstorm certification required? No separate windstorm certification is required beyond standard code wind-load design. The county's own PV Requirements document addresses wind loading only via the standard CRC §R324.4.1.2 component-and-cladding reference to Table R301.2(2)/(3) (adjusted for height and exposure) — there is no Banning/Barstow-style special-wind-region or minimum-mph certification called out. 85% · department handout (read in full)
• Is a Specific Use Permit or Council approval ever required? Not required for a standard rooftop retrofit. A large or nonconforming ground-mounted system that cannot meet the applicable zoning district's accessory-structure standards could require a Special Use Permit or Variance under the county's general zoning process (Title 9, Ch. 2, Arts. 6 and 8), but no solar-specific SUP/Council-approval trigger is codified. 62% · codified ordinance (inference)
• Is there a system-size cap on residential generation? No codified system-size cap (no AB 2188-era 10 kW AC / 30 kW thermal figure, or any other number, was found). 84% · codified ordinance (control-checked absence)

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? Licensed electrician, as a practical matter. 85% · department handout
• Must the contractor be registered with this authority before applying? No separate county contractor-registration requirement found — the county verifies the state CSLB license number and workers' compensation coverage (per §8-9.01 and the PV Requirements form fields) but does not require prior registration with the county itself. 74% · codified ordinance
• Is a homeowner permitted to self-install and self-permit? No, as a practical matter — the county's own handout states the CEC 'Qualified Personnel' requirement 'will not allow most homeowners to install these systems.' A homeowner could still pull an owner-builder permit under Bus. & Prof. Code §7044 (referenced in County Code §8-9.05) and hire a licensed electrician to perform the actual PV work, but self-INSTALLATION is effectively barred by the county's own document. 78% · department handout + codified ordinance

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? Per the county's own Solar Submittal Checklist: completed permit application (owner/contractor/agent signatures), workers'-comp forms, contractor license verification, project description; two sets of plans comprising a site plan (major-component locations), a roof layout plan (module layout, 3'-0" perimeter setback, roofing type), an electrical single-line diagram (array configuration, calculations, conductor types/sizes, overcurrent protection, inverter, disconnects, required signage, AC connection point, and battery/battery-box details if applicable); structural calculations (existing roof + added PV load, roof AND ground snow load verification, module attachment, rack snow/wind loads, and a foundation plan/calcs for ground- or pole-mount); and equipment specification sheets (modules, inverters, MPPTs, combiner box(es), disconnects, mounting-rack snow-load rating, and rack fire-rating listing). 96% · published checklist
• How many copies, and in what format? Two complete sets of plans. 92% · department handout
• Is a site plan required, and what must it show? Yes. Must show the location of all buildings on the property and the location of the PV unit on the property (PV Requirements #1), and separately the location of all major solar components (checklist). 95% · department handout
• Is a one-line / three-line diagram required? Yes — a one-line diagram of the service-entrance system AND a three-line diagram showing individual conductor types/sizes, conduit sizes and connection points, plus a roof plan showing new/existing equipment and available fault current at the AC disconnect. 97% · department handout
• Are string and conductor calculations required? Yes — the checklist requires 'electrical calculations' and conductor types/sizes on the single-line diagram, and the Requirements handout requires a load-calculation worksheet whenever the main breaker is being de-rated. 90% · published checklist
• Is a structural PE stamp required, and at what threshold? A California-licensed structural Engineer's stamp/signature is required essentially always for the roof-mount structural evaluation — there is no stated kW or weight threshold below which it is waived. The Requirements doc: 'Existing roof construction must be evaluated for local geographic and climatic design criteria as well as imbalanced load... by an Engineer licensed in the State of California for structural elements. Any structural plan sheets must be stamped and signed by the Engineer.' It also flags a hard structural ceiling: max additional roof loading of 5 psf + a 50-lb point load for truss-framed roofs before engineering is required to show the framing can carry it. 90% · department handout

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? No dedicated online permit-application portal was found. Applications are paper forms (downloaded PDFs) submitted at the Quincy counter or an after-hours drop box in Quincy or Chester. GovPayNet is used only for fee payment, and a separate 24/7 phone line + a public Google Calendar are used only for inspection scheduling — neither is an application portal. 76% · department page (reviewed in full)
• Can the whole application be completed online? No — see Q20; there is no online application system, only paper submittal. 76% · department page (reviewed in full)
• What does a residential solar permit cost? $239.50 residential (Electrical permit $166.00 + ½-hour plan review $73.50). Commercial PV is $371.50. A separate 'Service Upgrade for PV System' line is $166.00 residential / $298.00 commercial, and a 'Stationary Battery System Residential' line is also $239.50. 88% · fee schedule / department handout
• How is the fee calculated? Flat — a flat electrical-permit fee plus a flat half-hour plan-review fee; not valuation-based, not per-kW, per-panel, or tiered. 86% · fee schedule
• Is there a separate plan-check fee? Yes — the plan-review component ($73.50 for a half hour) is itemized separately from the $166.00 electrical-permit fee, even though both are billed together as one $239.50 total. 88% · 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? ~2-4 weeks average for a complete submittal (not solar-specific — this is the Building Department's general stated turnaround, dependent on workload). 78% · department FAQ
• How long is an issued permit valid before it expires? 24 months after issuance; becomes invalid earlier if work is not commenced within 180 days or is suspended/abandoned for 180 days. One or more 180-day extensions may be granted by the Building Official for good cause. 92% · codified ordinance
• Which utility handles interconnection here? PG&E, for the majority of unincorporated Plumas County (confirmed from the Building Department's own page). However, Plumas-Sierra Rural Electric Cooperative (PSREC) — headquartered in the City of Portola per its own site — very likely serves the City of Portola and the eastern Plumas County/Sierra Valley area instead of PG&E; this could not be confirmed from a Portola-city or Plumas-County document (only from PSREC's own site), so it is reported as a probable utility split rather than a confirmed one. 70% · department page + utility's own site
• Where does the utility sit in the sequence? After permit / gated on the AHJ's final inspection — Plumas County independently bars any utility (by name, in county code) from permanently connecting electrical power before the county's own final inspection has been made and approved by the Building Official or a designated inspector (§8-9.05). This mirrors PG&E's own Rule 21 §D.13.b, which processes Permission to Operate only upon 'evidence of Applicant's final electric inspection clearance from the Governmental Authority having jurisdiction.' 85% · codified ordinance + 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, via the 2025 CEC (Part 3 of Title 24), effective 1 Jan 2026 — automatically in force under the county's own 'evergreen' adoption clause, Plumas County Code §8-1.01, which adopts 'the current California Building Standards Code... For purposes of this section, "current" means the 2007 edition and any subsequent triennial edition,' updating 'by operation of law' whenever the state cycle changes. NOTE: the Building Department's own PV Requirements handout (last revised 3 May 2023) still directly instructs applicants to 'Specify the applicable codes: 2019 CRC, and 2019 CEC' — a real, sourced two-cycle lag between the codified evergreen standard and the department's own operational solar handout. 84% · codified ordinance + department handout (conflict noted)
• Which building code edition is in force? Current CBC (2025 edition, i.e. Part 2 of Title 24, effective 1 Jan 2026), via the same §8-1.01 evergreen adoption clause described in Q29. 86% · codified ordinance
• Which fire code edition is in force? Current CFC (2025 edition, i.e. Part 9 of Title 24, effective 1 Jan 2026) — adopted via the same §8-1.01 omnibus clause (which lists 'Part 9 [including Appendix Chapter 4 and Appendix H]' among the adopted parts), NOT via a separate Fire Prevention chapter (Title 4, Ch. 2, is a pre-CFC set of firebreak/fireworks/fuel-storage ordinances from the 1970s-90s with no CFC adoption language of its own). Enforcement of the CFC/WUI provisions for R-3 occupancies is separately assigned by ordinance to the county's own Building Official, per §8-1.09 — not to a fire agency. 86% · codified ordinance
• Are there local amendments to any of the above? Yes. Local amendments found in Title 8, Ch. 1: §8-1.02 (no-fee permits for small accessory/agricultural buildings), §8-1.04 (anti-glare roof-covering amendment to CBC §1506.1 — bars mirror-like/reflective roofing), §8-1.07 (added ice-dam roof flashing requirement, CBC §1507), §8-1.08 (added frost-depth footing requirement, CBC §1805 — 12in into undisturbed soil, 18in total minimum depth), §8-1.09 (CFC/WUI enforcement assigned to the Building Official), and in Ch. 9: §8-9.05 (local pre-final-inspection energization bar) and §8-9.06.1 (CBC §1807.2.1 slab damp-proofing amendment). 95% · codified ordinance
• What is the installation judged against? The adopted (evergreen) CBC/CRC/CEC/CFC parts of Title 24 CCR as locally amended (Q32), plus the Building Department's own PV Requirements and Solar Submittal Checklist as the operational plan-check standard. 88% · codified ordinance + department handout

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? Standard (unamended) 2019 CRC §R324.6 roof access/pathway/ridge-setback rules, quoted verbatim in the county's own PV Requirements handout: minimum two 36in-wide pathways from lowest roof edge to ridge (one on the street/driveway side); an 18in clear setback at the ridge on both sides where the array covers ≤33% of plan-view roof area, 36in where it covers more (or 66%/18in and >66%/36in with an NFPA 13D/P2904 residential sprinkler system installed); a 36in pathway to any emergency escape/rescue opening; exceptions for detached non-habitable structures and for roofs ≤2:12 slope. 93% · department handout (quoting adopted CRC)

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. The county's own PV Requirements handout cites 'CEC 690.56(c)(1)' as the rapid-shutdown authority — this citation is itself in error (690.56(C) is the NEC/CEC placarding section for interconnected systems; rapid shutdown is properly codified at NEC/CEC §690.12). Recorded as written, not corrected. Which EDITION of the NEC governs is the evergreen-clause figure from Q29 (currently 2023 NEC via the 2025 CEC), though the same handout separately tells applicants to cite the superseded 2019 CEC. 80% · department handout (citation error noted)

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 county-specific placard list — the handout requires only that the system be 'posted with all applicable warnings, signage and plaques per CEC Articles 690 and 705' (a generic cross-reference), plus 'REQUIRED SIGNAGE' as a line item on the submitted single-line diagram in the checklist, without itemizing which placards. 80% · department handout
• Does the authority specify placard wording of its own? No — the county does not specify its own placard wording; it only cross-references CEC Articles 690 and 705 generically. 86% · department handout (control-checked absence)
• Does it specify letter height, colour or material? No — no letter height, colour or material is specified by the county anywhere in its PV documents. 86% · department handout (control-checked absence)
• Does the UTILITY specify placards beyond the AHJ's? PG&E's own Rule 21 requires a visible, lockable AC/interconnection disconnect with open/closed position markings (§H.1.d), shown on the single-line diagram, beyond anything the county itself specifies. For the eastern-county area that may instead be served by Plumas-Sierra Rural Electric Cooperative (see Q22), PSREC's own interconnection/placard rules were not reached within this run. 70% · utility tariff
• Where must the labels be placed? At the AC disconnect(s)/lock-offs at breakers, and at the service panel — the PV Requirements handout requires the disconnecting means to be 'within sight of any photovoltaic equipment' (CEC 422.30; CEC 690 Part 3), and PG&E's Rule 21 separately requires its own visible disconnect to be reachable 24/7. 78% · department handout + 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.

• Must equipment be on a specific approved list? Yes — panels/modules must be listed and labeled per UL 1703, inverters per UL 1741 (utility-interactive listing for grid-tied systems), per CRC §R324.3.1 as quoted in the county's own handout; the checklist separately requires cut sheets/listings for modules, inverters, MPPTs, combiner boxes, disconnects, and a fire-rating listing for the mounting rack. 95% · department handout
• Are batteries permitted, and under what conditions? Yes. Stationary storage battery systems must be installed per manufacturer's instructions/listing and comply with CRC §R327 and CFC Chapter 12. The county additionally requires listing/labeling to UL 9540A-2018, installed per NFPA 855, OR housed in a standalone structure of ignition-resistant construction (CRC §R337) or non-combustible construction. 95% · department handout
• Is there a separate ESS permit or inspection? Priced as a distinct permit line ('Stationary Battery System Residential,' Elect. $166 + ½hr plan review $73.50 = $239.50, separate from the PV line) though it can be submitted alongside a PV permit. Whether it triggers a distinct SITE inspection visit (versus being rolled into the same PV final) is not stated by the county. 70% · fee schedule (partial)
• Is a ground mount treated as a structure? Yes — the Planning Department requires that 'all freestanding units must meet accessory structure provisions for their particular zoning district,' and CEC 690.33(b) guarding-against-contact applies to all freestanding units. Ground-mounted systems are separately required (CRC §R324.7) to be designed per CRC §R301, with the fire-separation distance from structures 'determined by the local jurisdiction' — Plumas County has not codified its own figure for that distance (see not_found). 88% · department handout
• Is there a local rule on service upgrades or busbar sizing? No local busbar-sizing or service-upgrade amendment found (no Palm-Springs-style 225A minimum-busbar or attic-ambient-derating rule). Title 8 has no dedicated Electrical Code local-amendment chapter at all; the only PV-adjacent service item is a flat 'Service Upgrade for PV System' fee line ($166 residential / $298 commercial), which is a fee, not a technical sizing rule. 82% · codified ordinance (control-checked absence)

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 — a dedicated 24/7 Inspection Request Phone Line, (530) 283-6001. 95% · department page
• How much notice is required? Effectively 1 business day — requests must be received 'no later than 3 PM of the working day before the requested inspection.' Weekend requests roll to the following Tuesday; requests left on a county holiday roll to the second day after the holiday. 93% · department page
• Are same-day or AM/PM windows offered? No AM/PM window system — the daily Inspection Schedule Calendar 'is not finalized until 8:30 a.m. on the day of the inspection,' is described as an estimate only, and applicants are told to 'allow one hour before and after estimated inspection time.' 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 — self-performed by the county's own Building Inspectors (Bill Osborn, Chase Ramirez per the current staff directory); no delegation to a firm or another agency was found for the final building/electrical inspection. 88% · department staff directory
• If delegated, to whom? Not applicable — inspection is self-performed by the County Building Department; it is not delegated. 85% · department staff directory

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.

Nothing recorded for Plumas County on this step yet — 2 questions checked and found unpublished. The guidance above is general.

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, stamped plans on site — the Inspection Request page's general guidance requires that actual conditions match the approved plans, implying the approved plan set (and presumably the permit card) must be available for the inspector to compare against; not stated as an explicit itemized list for PV. 62% · department page (inference)
• Does the inspector verify labels and listings? Very likely yes, by inference — the checklist requires equipment cut sheets/listings and 'REQUIRED SIGNAGE' as approved plan-check items, and the Inspection Request page's general 'Tips for Successful Inspections' states 'Work must match what is shown on the approved plans,' which would include listed equipment and signage as drawn. Not stated as an explicit inspector checklist item for PV specifically. 65% · department page (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 inspection approval/sign-off by the Building Official or designated Inspector — County Code §8-9.05 frames the gating event as 'the final inspection has been made and the approval signed by the Building Official or the Official's designated Building Inspector'; no separate Certificate of Occupancy, 'green tag' or letter terminology was found for a standard residential PV retrofit. 66% · codified ordinance (inference)
• How are corrections issued and cleared? If actual site conditions differ from the approved plans, or the work cannot be followed against the approved plans, the applicant must have the design professional revise and RESUBMIT the plans to the county for approval BEFORE calling for an inspection — i.e., corrections are cleared by a plan resubmittal, not an on-site correction notice process. 68% · department page