Santa Barbara 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 only. The County of Santa Barbara Planning & Development Department, Building & Safety Division, is the AHJ. The eight incorporated cities (Santa Barbara, Goleta, Carpinteria, Lompoc, Santa Maria, Solvang, Buellton, Guadalupe) are separate AHJs, with one documented exception: the County runs the SolarAPP+ automated review path for the City of Buellton as well as for the unincorporated area. 92% · adopting ordinance
• What does this authority permit itself, and what does it delegate? Both. Building AND electrical sit in the same division - Planning & Development, Building & Safety. Nothing is delegated away. Fire review/inspection attaches separately: Santa Barbara County Fire Department for most of the unincorporated area, and the independent Montecito Fire Protection District and Carpinteria-Summerland Fire Protection District where applicable. 88% · adopting ordinance
• Is a permit required for a residential rooftop PV system? Yes. An electrical permit is required for a roof-mounted residential PV system; there is no permit-free threshold. 93% · published handout
• Is there a separate electrical permit, or is it combined? Combined - one permit. Residential rooftop PV is priced and issued as an ELECTRICAL permit, and the county's e-PV application is a single application covering the PV system and an energy storage system under 20 kWh together. 82% · fee schedule
• Is a HOA or architectural approval required first? No. HOA or architectural approval is not a county permit condition - Gov. Code 65850.5 forbids conditioning approval on it, and the county's solar ordinance (Chapter 10 Article XVI) contains no such condition. The county's own handout does warn that 'If the project is located in a historical district, in a homeowner's association, within the CA Coastal Zone or is a ground mount system, additional requirements for review may be required', but that is a caution about private/other-agency requirements, not a county permit step. 75% · published handout
• Is there a historic-district review? No county-wide historic-district review for solar. Both development codes affirmatively exempt solar from design review: LUDC s.35.30.160 and MLUDC s.35.430.160 each open 'Solar energy systems located on the roof of an existing structure and freestanding solar energy systems are exempt from design review and do not require planning permit approval'. The county does maintain Historic Landmark and Place of Historic Merit designations and a Historic Landmarks Advisory Commission, and the expedited handout warns that a project 'located in a historical district' may attract additional review - so a designated landmark should be checked case by case. 68% · development code
• Is a wind or windstorm certification required? No wind or windstorm certification is required as a separate document. But wind exposure is a hard gate on the expedited path: the eligibility checklist requires that 'The dwelling is not located in Wind Exposure D (structure is not on a hill with an average slope greater than 15%, or within 200 yards of the ocean or large coastal bay)'. In a coastal county that pushes a lot of beachfront and hillside jobs out of the expedited route into engineered design. 80% · published handout
• Is a Specific Use Permit or Council approval ever required? Not for ordinary rooftop PV - it is administratively approved by the Building Official under Chapter 10 Article XVI. Discretionary approval appears in three places. (1) INLAND and MONTECITO: a 'Solar Use Permit' may be required if the Building Official 'has a good faith belief that the solar energy system could have a specific, adverse impact upon the public health and safety'; it is noticed, and both the decision to require it and the decision on it are appealable to the Planning Commission. The Building Official may only deny it on written findings of specific adverse impact with no feasible mitigation. (2) COASTAL ZONE: a Coastal Development Permit is required where the CZO exemption is disapplied (see Q3/Q25/Q47 notes and CZO s.35-51B.B.1). (3) Building/grading permits in a designated Special Problems Area cannot issue until the Special Problems Committee has reviewed the plans (Sec. 10-1.5, new CBC 105.1.4). No Board of Supervisors approval is ever required. 82% · development code
• Is there a system-size cap on residential generation? No cap on residential generation in the zoning or building codes. The caps that exist are gates on particular fast-track routes: 10 kW AC nameplate or 30 kW thermal defines a 'small residential rooftop solar energy system' for the Chapter 10 Article XVI expedited procedure and for the eligibility checklist; the e-PV email application route requires total inverter continuous AC output of 15 kW or less and ESS under 20 kWh total; and the standard plan itself is limited to 10 kW AC, two inverters, a 120/240 V single-phase service and a busbar of 225 A or less. 85% · adopting 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. A California-licensed contractor of class B, C-10 or C-46 is the expected applicant and must sign; homeowners retain the state owner-builder route, but every published county path is written for a licensed contractor. 68% · permit application form
• Must the contractor be registered with this authority before applying? No separate county contractor registration was found. What is required is (a) an Accela Citizens Access account, (b) for the email path, a 'county provided fax/email permitting agreement (for new accounts)', and (c) for SolarAPP+ only, prior registration with SolarAPP+ itself (not with the county). 70% · department page
• Is a homeowner permitted to self-install and self-permit? Yes in principle - state owner-builder law is not displaced and Chapter 10 contains no prohibition - but the county publishes no owner-builder solar path, and both the expedited handout and SolarAPP+ are built around a licensed contractor's signature. 55% · adopting 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 Expedited Residential Rooftop Photovoltaic handout: (a) completed Eligibility Checklist, filled out, signed and dated; (b) Electrical Plan showing location of main service/disconnects/inverters with service size and bus bar rating, module and string counts, make/model/spec sheets for panels, racking, attachment hardware, inverters, optimizers, disconnects and combiner boxes, one-line diagram with all components and wire sizes, grounding/bonding, conductor and conduit type/size/fill, equipment labelling per CEC 480, 690 and 705, and a site diagram; (c) Roof Plan with roof layout, panel layout, racking attachment points, conduit runs, PV system fire classification, locations of all required labels and markings, code-compliant access pathways, and notes on roof type, number of layers, framing size and spacing, and roof slope; (d) Structural Plan where required. The e-PV application adds the completed permit application, the smoke-alarm/carbon-monoxide self-certification (residential work over $1,000), and the fax/email permitting agreement for new accounts. 88% · published handout
• How many copies, and in what format? Digital only, one flattened PDF. Since 5 July 2023 all applications including plans and technical documents must be submitted through Accela Citizens Access. PDFs must be flattened/optimised version 1.4 or greater, contain no layers, not exceed 100 MB, have thumbnails listing sheet numbers, be a single merged PDF for the plan set, and be legible printed at 11x17 minimum for limited scopes (24x36 for full sets). The parallel PV email route asks for 11x17 plans to rmpvpermits@countyofsb.org (South) or ncbuild@countyofsb.org (North). No paper copy count is published. 85% · published handout
• Is a site plan required, and what must it show? Yes. The site diagram must show the arrangement of panels on the roof, a north arrow, lot dimensions, and the distance from property lines to adjacent buildings/structures (existing and proposed). The e-PV application additionally requires a Site Plan showing the location of all new and existing related electrical equipment plus a vicinity map. 88% · published handout
• Is a one-line / three-line diagram required? Yes. A one-line (single-line) diagram of the system including all components and wire sizes is required, and the county's adopted Solar PV Standard Plan supplies pre-drawn single-line diagrams to complete. 92% · published handout
• Are string and conductor calculations required? Yes. Voltage calculations, conductor and conduit type/size and number of conductors per conduit section, string counts and OCPD sizing are all required. The county's Standard Plan works them as numbered steps (maximum modules in series per CEC 690.7, source-circuit OCPD, inverter DC disconnect rating, and the 705.12(D)(2) busbar check). 88% · published handout
• Is a structural PE stamp required, and at what threshold? Conditional. No engineer's stamp is required where there are no visible structural deficiencies or deflection in the roof structure and maximum racking attachment spacing is 6 feet on centre (for conventional framing and for factory-built trusses where the contractor confirms no attachment within 1 foot of any top-chord splice); where that cannot be confirmed, or trusses are at 16 inches on centre, spacing drops to 4 feet on centre alternating. Outside that, structural drawings and calculations must be stamped and signed by a California-licensed civil or structural engineer. 85% · published handout
• Is an electrical PE stamp required, and at what threshold? Not required. No electrical PE stamp threshold is published anywhere in the county's solar package; what is required instead is the signature and licence number of a C-10 or C-46 contractor on the plan cover sheet to take responsibility for the PV electrical design. 78% · permit application form

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? Accela Citizens Access (https://aca-prod.accela.com/sbco/Default.aspx) is the permit portal, and SolarAPP+ is the automated plan-review front end for eligible residential rooftop PV. There is also a live email route for PV: rmpvpermits@countyofsb.org (Santa Barbara office) and ncbuild@countyofsb.org (Santa Maria office). 92% · portal landing page
• Can the whole application be completed online? Yes. Application, document upload, fee payment and status lookup are all online. Santa Barbara County offers SolarAPP+ automated approval for residential rooftop PV, which then feeds an online Accela application. Only inspection booking is off-portal (phone or email). 88% · portal landing page
• What does a residential solar permit cost? $450 base for systems 15 kW or less, plus $15 for each kW above 15 kW, plus a 6.00% Technology & Records Maintenance surcharge - about $477 all-in for a typical residential system. There is no separate inspection fee: the schedule states the inspection is 'State limited fee collected under plan check'. 90% · fee schedule
• How is the fee calculated? Tiered / per kW - a flat base fee up to 15 kW, then a per-kW adder. Explicitly not valuation-based. 92% · fee schedule
• Is there a separate plan-check fee? No. For residential PV there is one fee, taken on the plan-check side; the inspection column for that row reads 'State limited fee collected under plan check'. The generic $79 Intake Processing Fee and $156 Issuance Processing Fee are listed separately in the schedule and are not shown as applying to the PV row. 72% · 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? Over the counter where the standard submittal is used - the handout says such applications 'may be approved "over the counter" at our office when staff is available or may be submitted "over the counter" electronically', and that permits not approved over the counter 'should be reviewed within 3 to 5 days'. The county's web page advertises a '10-day expedited plan review' for the same product. SolarAPP+ is instant automated review. Final Plan Check Processing (agency sign-offs and fee verification) 'may take up to five business days'. 72% · published handout
• How long is an issued permit valid before it expires? 12 months to start work. Sec. 10-1.8 (replacing CBC 105.5, first sentence): 'Every permit issued shall become invalid unless the work on the site authorized by such permit is commenced within 12 months after its issuance, or if the work authorized on the site by such permit is suspended or abandoned for a period of 180 days after the time the work is commenced.' Separately, a plan-review application expires 365 days after filing, extendable in 180-day increments provided the California Building Standards Code has not changed (Sec. 10-1.7). 88% · adopting ordinance
• Which utility handles interconnection here? Two investor-owned utilities split the unincorporated county. Southern California Edison serves the South Coast - Carpinteria, Summerland, Montecito, the unincorporated fringes of Santa Barbara and Goleta, Isla Vista and the Gaviota coast. Pacific Gas & Electric serves North County and the Santa Ynez Valley - Santa Maria, Orcutt, Guadalupe, Los Alamos, Los Olivos, Santa Ynez, the Solvang and Buellton area, the Lompoc valley outside the City of Lompoc, and Cuyama. Central Coast Community Energy (3CE) is the community-choice generation provider across much of the county but is NOT the interconnecting utility - interconnection stays with SCE or PG&E under CPUC Rule 21. (The City of Lompoc runs its own municipal electric utility, but that is inside an incorporated city and out of scope.) 72% · county climate action plan
• Where does the utility sit in the sequence? Parallel, and never a precondition of the permit. The ordinance is explicit that the county permit does not authorise interconnection and that the applicant carries the utility approval separately: 'Permit issuance does not authorize an applicant to connect the small residential rooftop solar energy system to the local utility provider's electricity grid. The applicant is responsible for obtaining such approval or permission from the local utility provider.' Permission to operate follows the county's final inspection. 85% · adopting 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? 2023 NEC. The county adopts the 2025 California Electrical Code (Sec. 10-3.1, Ord. No. 5270, 11-18-2025), which is the 2023 NEC as Title 24 Part 3, with no local amendment to Article 690. 85% · adopting ordinance
• Which building code edition is in force? 2025 California Building Code and 2025 California Residential Code, in force since 1 January 2026. Chapter 10 was repealed and re-enacted in its entirety by Ord. No. 5270, adopted 18 November 2025, to adopt the 2025 cycle: CAC, CBC, CRC, CEC, CPC, CMC, Energy Code, Wildland-Urban Interface Code, Historical Building Code, Fire Code, Existing Building Code, CALGreen and Referenced Standards Code, plus the 2024 International Property Maintenance Code. One- and two-family dwellings and townhouses up to three storeys are routed to the CRC by Sec. 10-1.2. 93% · adopting ordinance
• Which fire code edition is in force? 2025 California Fire Code, plus portions of the 2024 International Fire Code, with local amendments. Chapter 15 Article I was repealed and re-enacted by Ord. No. 5269, adopted 18 November 2025 (it formerly adopted the 2022 CFC and 2021 IFC). Chapter 10 Article XIX separately adopts the 2025 California Wildland-Urban Interface Code with amendments. 92% · adopting ordinance
• Are there local amendments to any of the above? Yes - substantial local amendments, several of which touch solar directly. (a) FIRE: CFC 1205.5 is amended to read 'Ground-mounted photovoltaic panel systems shall be installed in accordance with this section and the Santa Barbara County Fire Department Development Standards. Setback requirements shall not apply to ground-mounted, free-standing photovoltaic arrays.' (b) WUI: Chapter 10 Article XIX amends CWUIC 613.5 to require 'A minimum of 30 feet of defensible space ... around ... ground-mounted photovoltaic panel systems which are 1,500 square feet or greater in combined panel area', and imports a five-foot ember-resistant ZONE 0 around structures. (c) BUILDING: numerous CBC Chapter 1 administrative replacements and CRC framing/bracing amendments (blocking to roof sheathing in seismic D0/D1/D2, R602.10.8.2 figure notes). (d) Article XVI is the local AB 2188 expedited-solar ordinance. NOTHING amends the rooftop PV provisions of CRC R329 or CFC 1205.1-1205.4. 88% · adopting ordinance
• What is the installation judged against? The 2025 California Electrical Code (2023 NEC) as adopted by Sec. 10-3.1, principally Articles 690 and 705, together with the approved plans and the manufacturers' listing/installation instructions. The county's adopted Solar PV Standard Plan states 'Systems must be in compliance with current California Building Standards Codes and local amendments of the authority having jurisdiction (AHJ)', and requires listed equipment per CEC 110.3 and equipment identified and listed for PV use per CEC 690.4(D). 85% · published 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? For ROOFTOP systems the county adds nothing: access pathways, setbacks and smoke-ventilation are the 2025 CFC 1205 and 2025 CRC R329 provisions as adopted, unamended, so the state 3-foot ridge setback / 18-inch case and the 36-inch pathways apply as the code allows. The county's own submittal documents state the requirement only as an outcome ('Clear access pathways provided'; 'PV system fire classification is provided'; 'A diagram of the roof layout of all panels, modules, clear access pathways and approximate locations of electrical disconnecting means and roof access points'). Extra local rules exist only for GROUND MOUNT - see Q47. HANDOUT STALENESS: the current Expedited Residential PV handout points installers to 'Section 324 of the California Residential Code' (dead - solar is now R329); the adopted Solar PV Standard Plan cites 'CRC R331.2 and CFC 605.11.1' (2016-cycle numbering); and the Submittal Requirements Bulletin points to a dead osfm.fire.ca.gov Solar PV Installation Guide URL. 78% · adopting ordinance

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 to NEC 690.12 as carried into the 2025 California Electrical Code (2023 NEC), with no county amendment. The county's adopted standard plan is written around it (module-level shutdown devices / DC-DC converter configurations with an 80 V AFCI cap in Table 2, and the rapid-shutdown labelling carried by the marking sheet). 80% · 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.

• Which placards does this authority require at the service equipment? The county's adopted Solar PV Standard Plan sets out the full placard set, prefaced 'CEC Articles 690 and 705 and CRC Section R331 require the following labels or markings be installed at these components of the photovoltaic system': WARNING INVERTER OUTPUT CONNECTION; DO NOT RELOCATE THIS OVERCURRENT DEVICE (705.12(D)(7), not required if the panelboard is rated not less than the sum of the ampere ratings of all overcurrent devices supplying it); WARNING DUAL POWER SOURCES / SECOND SOURCE IS PHOTOVOLTAIC SYSTEM / RATED AC OUTPUT CURRENT ___ AMPS AC / NORMAL OPERATING VOLTAGE ___ VOLTS (690.54 and 705.12(D)(4)); PV SYSTEM AC DISCONNECT / RATED AC OUTPUT CURRENT ___ AMPS / AC NORMAL OPERATING VOLTAGE ___ VOLTS (690.54); PV SYSTEM DC DISCONNECT / RATED MAX POWER-POINT CURRENT ___ ADC / RATED MAX POWER-POINT VOLTAGE ___ VDC / SHORT CIRCUIT CURRENT ___ ADC / MAXIMUM SYSTEM VOLTAGE ___ VDC (690.53); WARNING PHOTOVOLTAIC POWER SOURCE on junction/combiner boxes and conduit every 10 feet; WARNING ELECTRIC SHOCK HAZARD - DO NOT TOUCH TERMINALS - TERMINALS ON BOTH LINE AND LOAD SIDES MAY BE ENERGIZED IN THE OPEN POSITION (690.17); WARNING ELECTRIC SHOCK HAZARD - IF A GROUND FAULT IS INDICATED, NORMALLY GROUNDED CONDUCTORS MAY BE UNGROUNDED AND ENERGIZED (690.5(C), normally already on listed inverters); and for ungrounded systems WARNING ELECTRIC SHOCK HAZARD - THE DC CONDUCTORS OF THIS PHOTOVOLTAIC SYSTEM ARE UNGROUNDED AND MAY BE ENERGIZED (690.35(F)). Plus the 705.12 permanent plaque or directory denoting all electric power sources on or in the premises. 88% · published handout
• Does the authority specify placard wording of its own? Yes. The county publishes the exact placard wording itself, in the Solar PV Standard Plan it adopts as the submittal document for expedited residential PV - it is not a bare reference to the NEC. 85% · published handout
• Does it specify letter height, colour or material? Partly, as guidance rather than mandate. The county's standard plan carries this informational note: 'ANSI Z535.4 provides guidelines for the design of safety signs and labels for application to products. A phenolic plaque with contrasting colors between the text and background would meet the intent of the code for permanency. No type size is specified, but 20 point (3/8") should be considered the minimum.' No colour is mandated; no material is mandated beyond 'permanency'. The Santa Barbara County Fire Department adds only that 'All marking signs shall be installed per the current California Electrical Code' and 'Materials used for marking signs must be weather resistant'. 82% · published handout
• Is a site plan / facility map placard required, and what must it show? Yes, two distinct things. (1) At the service equipment: CEC 705.12 requires a permanent plaque or directory denoting all electric power sources on or in the premises, and the county's standard plan states this requirement in terms. (2) On the plans, not as a placard: a roof layout diagram showing all panels and modules, clear access pathways, and the approximate locations of the electrical disconnecting means and the roof access points - this is both a submittal item and an eligibility checklist item. 82% · published handout
• Where must the labels be placed? At the point of interconnection and at each disconnecting means: at the inverter output connection / backfed breaker in the panelboard; at the AC disconnect; at the DC disconnect; at the inverter; on junction and combiner boxes and on conduit every 10 feet ('WARNING: PHOTOVOLTAIC POWER SOURCE'); and a permanent plaque or directory of all electric power sources at the service equipment. The Submittal Requirements Bulletin's inspection list checks specifically for a sign identifying PV power source system attributes at the DC disconnect, a sign identifying the AC point of connection, and a sign identifying the switch for the alternative power system. Label locations must also be shown on the roof plan. 85% · published handout

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? The county does not specify it. Its adopted Solar PV Standard Plan lists 'SEPARATE AC DISCONNECT INSTALLED?: YES / NO' with an asterisk and the footnote '* Consult with your local AHJ and /or Utility', and the electrical plan must show the 'Locations of main service or utility disconnect'. So the location rule comes from SCE or PG&E, not from Santa Barbara County. 45% · published handout
• Must equipment be on a specific approved list? No approved-products list of the county's own. The requirement is the code default: listed and labelled equipment installed per its listing and labelling (CEC 110.3), equipment identified and listed for PV use (CEC 690.4(D)), and manufacturers' specification sheets provided for the inverter, modules, combiner/junction boxes and racking. The e-PV application requires 'Use of listed components specific for PV systems, modules, inverter, utility-interactive inverters, and combiner boxes' and 'Use of an engineered mounting system'. 85% · published handout
• Are batteries permitted, and under what conditions? Yes. Residential energy storage is permitted and is handled inside the same rooftop PV permit when it is under 20 kWh - the county's application form is titled 'Residential Roof Mounted Photovoltaic / Energy Storage Systems less than 20kWh' and requires that 'Total inverter capacity has a continuous ac power output of 15kW or less and the ESS is less than 20kWh total'. Technically ESS is governed by 2025 CFC Section 1207 and 2025 CRC R330 as adopted, with no local amendment. The expedited AB 2188 route in Chapter 10 Article XVI does NOT cover storage: its eligibility checklist requires 'Solar system is utility interactive and without battery storage', and the adopted Solar PV Standard Plan excludes 'systems that utilize storage batteries, charge controllers, trackers'. So a PV+battery job is permitted, but not through the standard-plan fast track. 82% · permit application form
• Is there a separate ESS permit or inspection? No, not for systems under 20 kWh - the ESS rides on the same application and permit as the rooftop PV. There is a wrinkle worth knowing: the county fire fee schedule in Chapter 15 Sec. 15-101 lists a construction permit '105.6.6 Energy Storage Systems $274.00' (and '105.6.21 Solar photovoltaic power systems $274.00'), yet Sec. 15-3's amendment of CFC 105.6 adopts only '105.6.2 Automatic sprinkler systems'. On the face of the ordinance the fire construction permit for solar/ESS was not adopted even though a fee for it is published. 65% · adopting ordinance
• Is a ground mount treated as a structure? Yes - and in Santa Barbara County a ground mount picks up materially more than a rooftop array. It is not covered by the rooftop-only planning exemptions (LUDC s.35.20.040(23) and CZO s.35-51B.B.2.n both read 'the addition of solar energy systems to the roofs of existing structures'), it is outside the Chapter 10 Article XVI expedited path (which requires a roof-mounted array on a one- or two-family dwelling), and the county's own handout flags 'is a ground mount system' as triggering additional review. It does get relief on two fronts: LUDC s.35.30.160 and MLUDC s.35.430.160 exempt FREESTANDING solar energy systems from design review and planning permit approval, and amended CFC 1205.5 says 'Setback requirements shall not apply to ground-mounted, free-standing photovoltaic arrays'. But it must be built to the Santa Barbara County Fire Department Development Standards (Standard #9, Ground Mounted Solar Arrays, rev. 05/09/2024) - digital plan submittal to pe.submittals@countyofsb.org and approval before site construction, plot plan at not less than 1 inch = 10 feet showing access, a vegetation clearance zone, all-weather access roads supporting a 20-ton vehicle, access roadways 12 feet wide with 16 feet horizontal and 13.5 feet vertical clearance, internal roadways 20 feet wide at no more than 15% slope with a perimeter road around the whole project, fire-department turnarounds and gate locking, 6-inch address numbers, no vegetation under or around the arrays, 10 feet clear either side of the access road, and possibly a water supply and a vegetation management plan. In the WUI, Chapter 10 Article XIX's amended CWUIC 613.5 requires 30 feet of defensible space around ground-mounted PV of 1,500 square feet or more. In Montecito, MFD Development Standard V requires a minimum 10-foot clearance for free-standing arrays up to 1,500 square feet, 30 feet above that, and 20 feet between arrays. 88% · fire department standard
• Is there a local rule on service upgrades or busbar sizing? No free-standing local ordinance rule, but the county enforces service and busbar limits through the eligibility gate and the standard plan: interconnection must be to a single-phase 120/240 V service with a busbar rating of 225 A or less, on the load side of the utility distribution equipment; the 705.12(D)(2) 120% sum-of-supply-OCPDs check is worked in Table 4 of the standard plan; 'Reduction of the main breaker is not permitted with this plan' (that pushes the job to the Comprehensive Standard Plan); and an existing or proposed 100 amp centre-fed service must be declared with its busbar rating on the application. 78% · published handout
• Is a specific mounting system or attachment spacing required? Yes, prescriptively. Use of an engineered mounting system on a code-compliant roof; listed components specific to PV. Current expedited handout: maximum racking attachment spacing 6 feet on centre for conventional framing and for factory-built trusses where no attachment falls within 1 foot of a top-chord splice, dropping to 4 feet on centre alternating where that cannot be confirmed or trusses are at 16 inches on centre. Fasteners: 5/16 inch diameter lag screws with 2.5 inch embedment into the rafter, or per the manufacturer's guidelines. Flush-mount geometry: modules parallel to the roof plane, a 2 to 10 inch gap between the underside of the module and the roof surface, no overhang of ridges, hips, gable ends or eaves, array covering no more than half of total roof area. The e-PV application form still states the older rule - rooftop distributed weight under 5 lb/sq ft, under 40 lb per attachment, supports at maximum 4'-0" on centre or provide calculations. 82% · published handout

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 or Email - not the portal. North County: 805-934-6232 or Inspection-North@countyofsb.org. South County: 805-568-3118 or Inspection-South@countyofsb.org. Email requests 'will receive an email acknowledgement confirming or denying your inspection request'. (Fire construction permit inspections are requested separately through Accela.) 90% · department page
• How much notice is required? Effectively one business day. The request must be submitted by 3 PM on the business day preceding the desired date, and inspections 'received are typically scheduled for the next business day if requested prior to 3pm'. The e-PV application states '24 hours advance notice required for inspection'. The older Submittal Requirements Bulletin adds that where next-business-day is unavailable 'inspection should happen within a five-day window'. 82% · department page
• Are same-day or AM/PM windows offered? Not published. No AM/PM window, no same-day option and no time-slot system appears anywhere on the department's inspection page; what is published instead is that an emailed request is acknowledged (confirming or denying), and 'You will be contacted the following day to advise you of your scheduled inspection'. Required information with each request: permit number (format xxBDP-00000-xxxxx or xxCNP-00000-xxxxx), project address, type of inspection, desired date, contact name and phone, and gate code if needed. 75% · 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's own Building & Safety inspectors perform the inspection. Chapter 10 Sec. 10-16.3 allows it to be a consolidated building-and-fire inspection, and adds that 'A separate fire safety inspection may be performed by the applicable fire protection agency'. 90% · adopting ordinance
• If delegated, to whom? Not delegated. Building and electrical inspection stays with County Planning & Development, Building & Safety. Only the optional separate fire safety inspection goes elsewhere - to the applicable fire protection agency: Santa Barbara County Fire Department across most of the unincorporated county, the Montecito Fire Protection District in Montecito, and the Carpinteria-Summerland Fire Protection District in the Carpinteria valley. 82% · adopting 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? For an eligible small residential rooftop solar system: ONE inspection. Sec. 10-16.3 reads 'For a small residential rooftop solar energy system eligible for expedited review, only one inspection shall be required. The inspection shall be conducted in a timely manner and may include a consolidated inspection by the building official and fire chief. A separate fire safety inspection may be performed by the applicable fire protection agency. If a small residential rooftop solar energy system fails inspection, subsequent inspection(s) are authorized.' The e-PV job card nevertheless prints three lines in order: ELECTRICAL BONDING, SUPPORTS & EQUIPMENT; FINAL BUILDING; FIRE DISTRICT. 85% · adopting ordinance
• Is a rough-in or mid-roof inspection required? No. Chapter 10 Article XVI requires only one inspection for an eligible small residential rooftop system, and no mid-roof or rough-in stage is published for solar. The job card's 'ELECTRICAL BONDING, SUPPORTS & EQUIPMENT' line is signed at the same visit as the final, not as a separate rough-in. 72% · adopting 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? Yes. Section 5 of the Submittal Requirements Bulletin publishes an inspection checklist: module count and model numbers matching plans and spec sheets, conductors and components installed in a neat and workmanlike manner, array properly grounded, electrical boxes accessible and connections suitable for the environment, array fastened and sealed per the attachment detail, conductor ratings and sizes matching plans, correct signage, and the equipment-rating checks above. For SolarAPP+ jobs the SolarAPP+ inspection checklist applies. The Santa Barbara County Fire Department's own inspection checklists are NOT currently available - its 'Inspection Requirements (Code Summaries)' page reads 'The Code Summaries are being updated. New documents will be added soon.' 80% · published handout
• What must be on site at inspection? The approved plans and the permit. 'Permit holders must be prepared to show conformance with all requirements in the field at the time of inspection. The approved plans and permit shall be onsite for the inspector.' For SolarAPP+ jobs the county adds 'Have your permit printed and available onsite for an inspector.' Where the inspector cannot get inside the dwelling - which is normal for a PV job - the smoke alarm and carbon monoxide self-certification is used instead, and the county's form says so in terms. 88% · published handout
• Does the inspector verify labels and listings? Yes, explicitly. The published inspection points include: 'Appropriate signs are property constructed, installed and displayed, including ... Sign identifying PV power source system attributes at DC disconnect; Sign identifying AC point of connection; Sign identifying switch for alternative power system', and 'Equipment ratings are consistent with application and installed signs on the installation' - inverter rating against the max voltage on the PV power source sign, DC OCPDs DC-rated at least as high, inverter rated for the site AC voltage on the AC point-of-connection sign, AC OCPD at least 125% of maximum current on the sign and no larger than the inverter listing label maximum, and the sum of the main and inverter OCPDs not more than 120% of the busbar rating. 88% · published handout

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 - a signed-off building final on the permit/job card, not a Certificate of Occupancy. The e-PV job card is signed at 'FINAL BUILDING'; the county describes the outcome as 'final approval and activation ... granted for the solar system'. Where a permit is revised (for example after a SolarAPP+ revision) 'a revised building permit and job card will be issued'. 78% · permit application form
• Who notifies the utility for PTO? Installer. The ordinance puts it beyond doubt: 'Permit issuance does not authorize an applicant to connect the small residential rooftop solar energy system to the local utility provider's electricity grid. The applicant is responsible for obtaining such approval or permission from the local utility provider.' The county does not notify SCE or PG&E. 85% · adopting ordinance
• Is there a re-inspection fee? $313 per hour, one-hour minimum, plus the 6.00% Technology & Records Maintenance surcharge and the 3.70% General Plan Maintenance surcharge. It is charged (a) after two failed inspections, (b) where the work is not accessible, or (c) where the work is not ready for a scheduled inspection. 88% · fee schedule
• How are corrections issued and cleared? Corrections are emailed to the project contact and cleared by resubmittal through the portal. 'Comments/corrections will be emailed to the project contact.' On resubmittal 'Staff will review responses and verify that corrections are resolved. Additional corrections may be issued if responses do not resolve prior comments/corrections issued and additional resubmittals may be necessary.' Applicants are 'encouraged to schedule a meeting with plan check staff before resubmittal'. On the expedited solar path specifically, an incomplete application draws 'a written correction notice detailing all deficiencies in the application and any additional information required to be eligible for expedited permit issuance', and a denial must be notified in writing within 45 days of receipt. Cost: the Re-check Fee of $313 per hour (one-hour minimum) bites 'upon the fourth and each successive check of the same plan'. 85% · department page