Alpine 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 95% · department page
• What does this authority permit itself, and what does it delegate? Both 90% · ordinance
• Is a permit required for a residential rooftop PV system? Yes 95% · published process document (PDF)
• Is there a separate electrical permit, or is it combined? Combined 75% · published process document
• Is a HOA or architectural approval required first? No (as a County permitting requirement) — though the County advises checking private CC&Rs where they exist 75% · ordinance
• Is there a historic-district review? No 70% · fee schedule (absence checked against Planning fee schedule and Title 15)
• Is a wind or windstorm certification required? No 55% · ordinance (absence checked)
• Is there a system-size cap on residential generation? No hard cap on residential solar system size; the ordinance instead defines a 'small residential rooftop solar energy system' eligible for expedited/administrative approval as one no larger than 10 kW AC nameplate (or 30 kW thermal) — larger residential systems are permittable but fall outside the expedited/ministerial track defined by §15.04.070 85% · ordinance

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 80% · department page
• Must the contractor be registered with this authority before applying? No 60% · department page (absence checked)
• Is a homeowner permitted to self-install and self-permit? Yes 85% · 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? Cover page (owner name, project address, scope of work, designer/contractor name, applicable code); Site plan (array location, main/grid disconnect locations, north arrow; for roof-mount: roof pitch, 3-ft eave-to-ridge pathway, 3-ft eave/ridge clearances; for pole-mount: location and property-line setback); Electrical single-line drawing (AC/DC disconnects, OCPD, grounding, GFP, combiner/junction boxes, conductor/conduit type and size, inverters, any batteries/charge controllers/generator connections); Manufacturer spec sheets for all PV equipment/mounting (listed by an approved testing agency; pole-mount requires a CA-licensed engineer's design); Detail sheet for equipment marking/signage (UL 969, CEC Art. 690) 95% · published checklist (PDF)
• How many copies, and in what format? Preferred: electronic submittal via the online portal (Building Division Online Portal / iWorq). If not submitted online, two (2) hard copies of the plan set are required. Electronic signatures are expressly allowed in lieu of wet signatures for small residential rooftop systems. 90% · published process document + ordinance
• Is a site plan required, and what must it show? Yes — must show location of the array, a readily accessible main/array disconnect location, grid power main disconnect (if applicable), north arrow; for roof-mount, roof pitch plus a minimum 3-ft-wide pathway from eave to ridge and 3-ft clearances from eaves/ridges; for pole-mount, location and setback from property lines 95% · published checklist
• Is a one-line / three-line diagram required? Yes 95% · published checklist
• Is a structural PE stamp required, and at what threshold? Yes, for pole/ground-mounted arrays only — 'Pole-mounted arrays will require a California licensed engineer's design.' No PE-stamp threshold is stated for standard roof-mounted residential arrays on a conforming roof structure. 85% · published process document

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 — 'Building Division Online Portal' at alpinecounty.portal.iworq.net 90% · department page
• Can the whole application be completed online? Yes 85% · published process document + ordinance
• What does a residential solar permit cost? No dedicated PV/solar fee line was found; solar permits appear to fall under the general valuation-based Building Fee Table (New Construction) in the Building Permit Information Guide — e.g. $226 for the first $2,500 of valuation, plus $36.13 per additional $1,000 up to $25,000, escalating through six valuation tiers to $9,513 + $6.78/$1,000 over $1,000,000 65% · published fee schedule (PDF)
• How is the fee calculated? Valuation 65% · published fee schedule
• Is there a separate plan-check fee? Yes 70% · published 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? Approximately 3 business days for a complete, expedited small-residential-rooftop-solar submission 90% · published process document
• How long is an issued permit valid before it expires? 12 months from issuance to commence/continue work (or if work is suspended/abandoned for 12 months); Building Official may grant one or more 180-day extensions; maximum open-permit validity is 4 years unless specifically approved otherwise 90% · ordinance
• Which utility handles interconnection here? Split by community: PG&E, Liberty Utilities (CalPeco), and Kirkwood Meadows Public Utility District (KMPUD) all serve different parts of the county — the County's own 2018 Multi-Jurisdictional Hazard Mitigation Plan lists 'Electricity: PG&E, Liberty Energy, & KMPUD' as the county's utility distributors, and its power-outage table separately shows outages recorded under 'Liberty' at Markleeville and near Woodfords (the county-seat area). KMPUD is a public utility district that generates/distributes its own electric service to the Kirkwood valley (drawing transmission via a PG&E-connected line), functioning as a municipally-owned utility rather than a CPUC-regulated IOU for that area. 70% · county hazard mitigation plan (PDF, dated Aug. 2018)
• Where does the utility sit in the sequence? Parallel — the County's building-permit approval is expressly independent of, and does not authorize, utility interconnection 80% · ordinance

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? 2020 90% · ordinance
• Which building code edition is in force? 2022 California Building Code / 2022 California Residential Code (based on the 2021 IBC/IRC) 95% · ordinance
• Which fire code edition is in force? 2022 California Fire Code (based on the 2021 International Fire Code) 95% · ordinance
• Are there local amendments to any of the above? Yes 95% · ordinance
• What is the installation judged against? The 2022 California Electrical Code (2020 NEC base, as locally amended), plus equipment listing by an approved testing agency (UL) and manufacturer's installation instructions 90% · ordinance + published process document

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? Minimum 3-foot-wide pathway from eave to ridge, and 3-foot clearances from both eaves and ridges, for roof-mounted arrays 95% · published process document

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, per NEC 690.12 (rapid shutdown) as incorporated via the 2022 CEC (2020 NEC base) — no local amendment to Article 690 or a distinct county rapid-shutdown rule was found 70% · ordinance (inference from adopted code edition)

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? Standard NEC Article 690 / UL 969 placards at the PV disconnect(s), inverter/AC-disconnect location, and main service (dual-power-source warning) — the County does not add placards beyond what CEC Article 690 requires 65% · published example diagram (image-only PDF, OCR'd)
• Does the authority specify placard wording of its own? No 75% · published process document
• Does it specify letter height, colour or material? Yes — 'Fade-resistant permanently affixed labels and signage with white lettering on a red background' 90% · published process document
• Is a site plan / facility map placard required, and what must it show? The required site plan itself functions as the facility map — it must show array location, main/array disconnect, grid main disconnect, north arrow, and (roof-mount) pathway/clearance dimensions; no separate freestanding 'facility map placard' at the meter was found beyond the standard NEC 705.10 directory inherited via the adopted 2022 CEC 65% · published process document

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 95% · published process document
• Are batteries permitted, and under what conditions? Batteries are permitted as part of the same PV permit — the required electrical single-line drawing must show 'additional standby systems including batteries, charge controllers, and generator connections (if applicable)' — but no distinct battery/ESS-specific fire or installation standard beyond general listing/manufacturer-instruction compliance was found 60% · published process document
• Is there a separate ESS permit or inspection? No 55% · ordinance (absence checked with controls)
• Is a ground mount treated as a structure? Yes (implied) 65% · published process document (inference)
• Is a specific mounting system or attachment spacing required? No solar-specific mounting/attachment-spacing rule was found; general structural design amendments in §15.04.030 (Case-Study wind-speed regions, elevation-based snow-load tables up to 488 psf, footing depth rules above 6,200 ft) apply to any roof or ground attachment, including PV racking, but are not solar-specific 60% · ordinance (absence checked with controls)

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 50% · department page (contact info)

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 90% · ordinance

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? One consolidated final inspection (potentially combining the building official and the local volunteer fire chief for the applicable response area) after plan-check approval and permit issuance; a follow-up inspection is authorized if the system fails the first one 80% · ordinance
• Is a rough-in or mid-roof inspection required? No 90% · ordinance

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? No dedicated field-inspection checklist is published — the County publishes a submittal/plan checklist (the Solar Expedited Permit Process) but no separate document describing what the inspector checks in the field 60% · department page (absence checked)
• Does the inspector verify labels and listings? Yes (inferred) 55% · published process document (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 (signed-off permit/inspection card) — no Certificate of Occupancy applies since a rooftop solar retrofit does not create a new occupancy 55% · ordinance (inference)
• Who notifies the utility for PTO? Installer 85% · ordinance
• Is there a re-inspection fee? $151.00 per hour (1-hour minimum, plus mileage) for a 2nd re-inspection; the same $151/hr rate applies to 'inspections for which no fee is specifically indicated or unpermitted work' 90% · published fee schedule (PDF)