City of Hanford

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% · fee schedule
• Is a permit required for a residential rooftop PV system? Yes 95% · department page
• Is there a separate electrical permit, or is it combined? Combined 78% · fee schedule
• Is a HOA or architectural approval required first? No 68% · state statute
• Is there a historic-district review? No evidence residential PV triggers Hanford's Historic Review process; the city's Master Fee Schedule lists a generic 'Historic Review' (no charge) and 'Historic Designation/Detachment of Site' fee under the Planning Division, but this applies to designated historic sites/structures, and no document ties it to the solar permitting path 55% · fee schedule
• Is a wind or windstorm certification required? No 80% · department page
• Is a Specific Use Permit or Council approval ever required? No - residential PV meeting the ministerial standard-plan/SolarApp+ path does not require a Specific Use Permit or Council approval; California Gov. Code §65850.5 requires ministerial, not discretionary, review of small residential solar systems statewide 78% · department page + state statute
• Is there a system-size cap on residential generation? 10 kW AC (CEC rating) is the ceiling for the city's expedited Eligibility Checklist path; larger residential systems are not barred outright but fall out of the expedited/Standard-Plan process into full plan review (fee schedule's residential/small-commercial PV tier runs up to 49 kW before the commercial 50kW+ tier applies) 85% · published 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 55% · standard plan form
• Must the contractor be registered with this authority before applying? No 62% · department page
• Is a homeowner permitted to self-install and self-permit? Yes 52% · inference from state law + city 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? Building Permit Application; Eligibility Checklist for Expedited Solar Photovoltaic Permitting; Inspection Guide for PV Systems; a Solar PV Standard Plan (central/string inverter or microinverter version); Structural Criteria for Residential Rooftop Solar Energy Installations (with engineer-stamped calcs if the array fails the Structural Criteria checklist) 90% · department page + checklists
• How many copies, and in what format? Digital upload only (PDF) via the Citizen Self-Service (EnerGov) portal; no physical-copy count is published 65% · department page
• Is a site plan required, and what must it show? Yes - a roof-layout diagram showing all panels/modules, clear fire-access pathways, and the approximate locations of electrical disconnecting means and roof access points 82% · published checklist
• Is a one-line / three-line diagram required? Yes 75% · standard plan form
• Are string and conductor calculations required? Yes 90% · standard plan form
• Is a structural PE stamp required, and at what threshold? No PE stamp required if the flush-mounted array meets every item on the city's Structural Criteria checklist (zero snow load, not Wind Exposure D, standard wind region, etc.); if any item fails, project-specific drawings and calculations stamped and signed by a California-licensed civil or structural engineer are required 88% · 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? Citizen Self-Service Portal (Tyler EnerGov), selfservice.cityofhanfordca.com/EnerGov_prod/SelfService 95% · portal landing page
• Can the whole application be completed online? Yes 88% · department page
• What does a residential solar permit cost? $425 flat for 1-15 kW via standard review ($200 permit issuance + $225 plan check, itemized as 'includes P.I. Fee'), or $157.50 flat if submitted through SolarApp+; +$15.00 per kW above 15 kW either way 93% · fee schedule
• How is the fee calculated? Tiered/Flat: flat $425 (standard) or $157.50 (SolarApp+) covers 1-15 kW, then $15.00 per additional kW above 15 kW; commercial systems ≥50kW use a separate per-kW schedule 90% · fee schedule
• Is there a separate plan-check fee? Yes - $225.00, itemized separately within the $425 standard-path total (not itemized under the $157.50 SolarApp+ flat fee, which appears to fold plan review into the automated check) 85% · 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.

• How long is an issued permit valid before it expires? Not stated in any Hanford-specific document found; the statewide default under the 2025 CBC (Sec. 105.5) is 180 days from issuance (and 180 days between required inspections) unless locally amended, and no local amendment to that section was found 55% · inference from state code + city page silence
• Which utility handles interconnection here? Southern California Edison (SCE) 72% · city financial record (Warrant Register) + Utility Division page

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 (statewide code cycle, effective 1 Jan 2026) 85% · department page
• Which building code edition is in force? 2025 California Building Code (CBC) 88% · department page
• Which fire code edition is in force? 2025 California Fire Code (CFC) 80% · department page
• Are there local amendments to any of the above? No local amendment ordinance was located; the Design Requirements page lists only the base 2025-cycle state codes with no itemized local amendments, and AB 130 (Stats. 2025 Ch. 22) bars any new more-restrictive residential amendment from 1 Oct 2025 through 1 Jun 2031 in any case 62% · department page
• What is the installation judged against? The 2025 CBC/CRC/CEC/CFC/CEnC as adopted, plus the city's own Solar PV Standard Plan and Structural Criteria toolkit documents for systems using the expedited path 82% · department page + checklists

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 Inspection Guide for PV Systems (dated 2015, citing 2013 CFC 605.11.3/CRC R331.4): 3-foot wide clear access pathway from eave to ridge on hip and single-ridge roofs (two such pathways on single-ridge roofs); modules kept back at least 18 inches from a hip or valley if panels are on both sides of it; modules kept no higher than 3 feet below the ridge top 62% · published inspection guide (dated 2015)

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 the currently-adopted 2025 CEC (module-level rapid shutdown per NEC 690.12, since the 2025 CEC is based on the 2023 NEC). The city's own published Inspection Guide for PV Systems still describes the older, pre-2017 array-boundary/directory scheme (citing 2011 CEC 690.4(H) and CEC 690.56(B)) - that document is dated 2015 and is now superseded on this specific point by the current code cycle stated on the Design Requirements page 70% · published inspection guide (dated 2015, flagged as outdated on this point)

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? WARNING: PHOTOVOLTAIC POWER SOURCE signage on conduits/enclosures; PHOTOVOLTAIC SYSTEM DISCONNECT labels on AC/DC disconnects; DC disconnect rating label (operating current/voltage, max system voltage, short-circuit current); AC output rating label at point of interconnection; a directory at the main service and PV inverter; shock-hazard warning labels on inverter/battery enclosures and ungrounded-circuit enclosures 78% · published inspection guide (dated 2015)
• Does the authority specify placard wording of its own? Yes 85% · published inspection guide (dated 2015)
• Does it specify letter height, colour or material? 3/8-inch (9.5 mm) minimum white letters on a red background, reflective weather-resistant material, for the 'WARNING: PHOTOVOLTAIC POWER SOURCE' conduit/raceway marking 85% · published inspection guide (dated 2015)
• Is a site plan / facility map placard required, and what must it show? Yes - a directory at the electrical service (and at the inverter, if in a different location) showing the location of the service disconnect and the PV system disconnect is required, per CEC 690.56(B)/705.10 80% · published inspection guide (dated 2015)
• Where must the labels be placed? At the main service disconnect (clearly visible from where operated); on all interior/exterior DC conduit, raceways, enclosures, junction and combiner boxes and disconnects, marked every 10 feet and within 1 foot of turns/penetrations; on the AC and DC disconnects; on the inverter; at the point of utility interconnection 80% · published inspection guide (dated 2015)

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 85% · published inspection guide (dated 2015)
• Are batteries permitted, and under what conditions? Batteries are excluded from the city's expedited/Standard-Plan Eligibility Checklist path ('Solar system is utility interactive and without battery storage' is a pass/fail condition); systems with batteries can instead be submitted through SolarAPP+, which explicitly supports 'Solar and Storage Projects' with its own separate installer training module, or through standard/full plan review 82% · published checklist + department page
• Is there a separate ESS permit or inspection? No separate ESS permit/fee line was found; the Master Fee Schedule has no 'battery' or 'energy storage' fee item, and SolarAPP+ treats solar+storage as a single combined project submission 65% · fee schedule
• Is there a local rule on service upgrades or busbar sizing? For the expedited path, the PV system must interconnect to a single-phase AC service panel of nominal 120/240 Vac with a bus bar rating of 225 A or less; systems needing a larger or upgraded service fall out of the expedited Eligibility Checklist and require standard/full plan review 85% · published checklist
• Is a specific mounting system or attachment spacing required? Yes - the Structural Criteria document specifies flush-mount qualifying assumptions and supporting anchor-spacing/attachment tables (e.g. up to 6-foot cross-slope anchor spacing under stated conditions) for one- and two-family dwellings; non-qualifying layouts require an engineer-stamped design 75% · 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 92% · department page
• How much notice is required? Requests accepted through 6:30 a.m. the day of the desired inspection; anything received after 6:30 a.m. is scheduled for the next business day - effectively same-day-if-early or 1 business day notice 88% · department page
• Are same-day or AM/PM windows offered? No distinct AM/PM window is offered; inspections are simply performed within the stated 7 a.m.-3:30 p.m. daily window 72% · 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 88% · department page
• If delegated, to whom? N/A - not delegated 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? A single final inspection is the documented stage for Standard-Plan PV systems, covering mounting/structural, electrical, grounding/bonding, fire-access, and labeling items per the city's Inspection Guide for PV Systems; no separate rough-in stage is described for the expedited path 65% · published inspection guide (dated 2015)
• Is a rough-in or mid-roof inspection required? No 68% · published inspection guide (dated 2015)

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 92% · published inspection guide
• What must be on site at inspection? The approved Standard Plan/Structural Criteria packet and permit card; for any job with valuation over $1,000 (which essentially all residential PV meets), a completed Form 53 Statement of Compliance (smoke/CO alarms) must be uploaded to the portal or verified by the inspector before a final inspection can proceed 65% · published form
• Does the inspector verify labels and listings? Yes 90% · published inspection guide (dated 2015)

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.

• Is there a re-inspection fee? $105.00 per re-inspection 90% · fee schedule