City of Bakersfield

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. The City of Bakersfield Building Division (Development Services Department) is the AHJ for residential rooftop solar inside the city limits. 95% · department page
• What does this authority permit itself, and what does it delegate? Both. The Building Division permits and inspects the building and the electrical work itself under a single building permit; nothing is delegated. Planning Division review is NOT required for rooftop PV of 10 kW or less, and Fire Department approval is NOT required either. 90% · published checklist
• Is a permit required for a residential rooftop PV system? Yes. A building permit is required for a residential rooftop PV system. 95% · published checklist
• Is there a separate electrical permit, or is it combined? Combined. One building permit covers the structural and electrical work; there is no separate electrical permit for a PV retrofit. 85% · application form
• Is a HOA or architectural approval required first? No. Approval of an application may not be based or conditioned on the approval of a homeowners association. 90% · ordinance
• Is there a historic-district review? Yes for a designated cultural resource or a property inside a designated historic district: BMC 15.72.160(A) bars issuing any permit for an 'alteration' without Historic Preservation Commission approval (public hearing, 10 days notice, appeal to Council). The exemption list in 15.72.160(B) lists 'solar' only under Plumbing (i.e. solar thermal) and the Electrical exemptions are limited to temp power, perm power, service, outlet/switch, motors and site electrical - rooftop PV is not named. Outside designated resources and districts there is no historic review. 55% · ordinance
• Is a wind or windstorm certification required? No. No wind or windstorm certification is required. Wind loading is handled inside the Structural Criteria checklist (wind exposure B or C, design wind speed thresholds, anchor fastener check) rather than by a separate certificate. 80% · published checklist
• Is a Specific Use Permit or Council approval ever required? No. Rooftop residential PV is ministerial. No Conditional Use Permit, Specific Use Permit or Council approval is required; BMC 15.56 makes the permit non-discretionary and Development Services describes the Building Division as issuing 'ministerial permits'. The only route to Council is an appeal from the Historic Preservation Commission on a designated cultural resource. 70% · ordinance
• Is there a system-size cap on residential generation? No cap on residential generation size in the Municipal Code. What is capped is the expedited route: BMC 15.56 and the Eligibility Checklist limit the streamlined/standard-plan process to 10 kW AC nameplate (or 30 kW thermal) on a one- or two-family dwelling; larger systems go through the standard permit process. The Standard Plan additionally restricts itself to a 120/240 V single-phase service with a busbar of 225 A or less. 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. A licensed contractor holding a valid City business tax certificate, or the property owner as owner-builder. 75% · portal
• Must the contractor be registered with this authority before applying? Yes. A contractor must hold a current City of Bakersfield business tax certificate (business licence) administered by the Finance Department Treasury Division, in addition to the state contractor licence, before a permit is issued. 70% · portal
• Is a homeowner permitted to self-install and self-permit? Yes. Owner-builder self-permitting is allowed; the city publishes an Owner Builder Declaration form and the permit application has an explicit Owner-Builder checkbox. 85% · application form

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 Submittal Requirements Bulletin: (a) completed permit application form; (b) completed Eligibility Checklist for expedited permitting; (c) completed Solar PV Standard Plan (standard electrical plan) for systems 10 kW or smaller; (d) a roof plan showing roof layout, PV panels, approximate location of the roof access point, code-compliant access pathways, the PV system fire classification and the locations of all required labels and markings; (e) completed Structural Criteria with supporting documentation. Manufacturer specification sheets for inverters, modules, combiner/junction boxes and racking must be provided. Non-qualifying systems instead need structural drawings and calculations stamped and signed by a California-licensed civil or structural engineer. 85% · published checklist
• Is a site plan required, and what must it show? Yes - a roof plan. It must show the roof layout, the PV panels/modules, the clear access pathways, the approximate location of the roof access point, the PV system fire classification, and the locations of all required labels and markings, plus approximate locations of the electrical disconnecting means. 90% · published checklist
• Is a one-line / three-line diagram required? Yes. The Solar PV Standard Plan includes a single-line diagram sheet with an equipment schedule (module, microinverter, junction boxes, solar load center, performance meter, utility external disconnect, main service panel) and a conductor, cable and conduit schedule that must be filled in. 85% · published checklist
• Are string and conductor calculations required? Yes. String and conductor calculations are required on the face of the Standard Plan: number of branch circuits and inverters per circuit, total AC system power, module VOC/ISC at STC, temperature-corrected DC voltage against Table 1, branch-circuit OCPD and minimum conductor/conduit size from Table 2, solar load centre sizing from Table 4, and the 705.12(D)(2) busbar check in Table 5. 85% · published checklist
• Is a structural PE stamp required, and at what threshold? Not required if the published Structural Criteria checklist is answered YES throughout - flush-mounted array parallel to the roof with a 2 to 10 inch gap, no overhang of ridges/hips/gables/eaves, modules plus supports no more than 4 psf (PV) or 5 psf (thermal), array covering no more than half of total roof area, anchor horizontal spacing within Table 1 for the measured roof slope and rafter spacing, rafter span within Table 2, and 5/16 inch lag screws with 2.5 inch embedment (or the manufacturer's fastener guidelines). If ANY item is NO, project-specific structural drawings and calculations stamped and signed by a California-licensed civil or structural engineer are required. 90% · published checklist
• Is an electrical PE stamp required, and at what threshold? No electrical PE stamp is required for a residential PV system permitted on the city's Standard Plan; no threshold is published. (The wet-stamp requirement the city publishes is for new COMMERCIAL buildings, where drawings, plans and calculations must be wet signed and stamped by a California Registered Design Professional.) 55% · 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? Clariti Permitting System customer portal (bakersfield.my.site.com), with Symbium used for the residential Solar, Service Panel Upgrade, Reroofing and EV Charging permit types. Payments go through Teller Online. The old Click2Gov system (bakeweb.ci.bakersfield.ca.us/Click2GovBP) is retired. 90% · portal
• Can the whole application be completed online? Yes. The whole application can be completed online through Clariti/Symbium, and BMC 15.56.040(B) expressly allows electronic submittal of a small residential rooftop solar application. 85% · portal
• What does a residential solar permit cost? $304 flat - 'Residential Solar System - Any Size', effective 1 July 2026 (previous adopted fee $296 from 23 April 2025). 85% · fee schedule
• How is the fee calculated? Flat. One fee per permit regardless of system size. 90% · fee schedule
• Is there a separate plan-check fee? No separate plan-check fee. The flat $304 covers both plan review and inspections. 80% · 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? 1 to 3 days ('Permits will be reviewed in 1-3 days'). In practice residential solar is now handled as a Clariti 'Quick Permit', a category the portal describes as 'issued for projects which do not require a plan review'. 60% · published checklist
• Which utility handles interconnection here? Pacific Gas and Electric Company (PG&E). 95% · city page
• Where does the utility sit in the sequence? Parallel. The city requires only a building permit - no utility sign-off is listed as a submittal item - so the PG&E Rule 21 / Solar Billing Plan interconnection application runs alongside the permit. The utility becomes a gate only at the end: PG&E requires the final electrical inspection clearance before granting Permission to Operate. 75% · utility DG manual

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, adopted as the California Electrical Code 2025 Edition. 90% · adopting ordinance
• Which building code edition is in force? 2025 California Building Code (based on the 2024 IBC) and 2025 California Residential Code (based on the 2024 IRC), effective 1 January 2026. 92% · adopting ordinance
• Which fire code edition is in force? The city ordinance still adopts the CALIFORNIA FIRE CODE, 2022 EDITION - it was not updated in the 2025 cycle. This is STALE, not an amendment: under H&SC 18938(b) the 2025 California Fire Code applies in Bakersfield from 1 January 2026 regardless of what BMC 15.65 says. 85% · adopting ordinance
• Are there local amendments to any of the above? Yes - but none of them touch solar PV. The word 'photovoltaic' does not appear anywhere in the Bakersfield Municipal Code. The live residential amendments are: BMC 15.05.020 to 15.05.170 (CBC deletions and modifications - dust abatement, sprinkler fire-area threshold reduced to 10,000 sq ft, foundations, footings, ACI 318, Appendix J grading); BMC 15.17.020 to 15.17.120 (CRC deletions including Appendix AT Solar Ready Provision, plus foundation, floor, wall, masonry and roof-sheathing amendments); BMC 15.30.040 (California Energy Code sec. 150.0(s) amended - Battery Energy Storage System ready for all new single-family residences of one or two dwelling units, requiring either a multi-mode BESS or a 120/240 V 125 A load centre on a 60 A feeder with spare 1 inch raceway); and BMC 15.65 fire-code amendments. Note the CRC deletion of Appendix AT (Solar Ready Provision) is the one deletion with a solar bearing. 85% · ordinance
• What is the installation judged against? The 2025 California Electrical Code (2023 NEC), including Articles 690 and 705, together with the 2025 CBC and CRC, the fire code, the city's Solar PV Standard Plan and Structural Criteria, and - by ordinance - the California Solar Permitting Guidebook. 85% · ordinance

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? Roofs steeper than 2:12: hip roofs need a 3 ft wide clear access pathway from eave to ridge on each roof slope carrying panels; single-ridge roofs need TWO 3 ft wide pathways from eave to ridge on each slope with panels; where panels are on both sides of a hip or valley they must be no closer than 18 in to it (panels on one side only of an equal-length hip or valley may abut it); and panels must be no higher than 3 ft from the top of the ridge for smoke ventilation. Pathways must be at a structurally sound location able to carry firefighters. 75% · fire code + amendments

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 by the code in force - CEC (2023 NEC) Article 690.12, adopted with zero California amendment under BMC 15.11.010. The City of Bakersfield publishes NOTHING of its own on rapid shutdown. 70% · 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 Inspection Guide Table 1 sets out the required signage: CEC 690.5(C) warning at the utility-interactive inverter and battery enclosure; 690.35(F) ungrounded-conductor warning on enclosures with ungrounded circuits; 690.14(C)(1) 'DC DISCONNECT IS LOCATED...' on the main service where DC wiring runs through the building; 690.14(C)(2) 'PHOTOVOLTAIC SYSTEM DISCONNECT' on the AC and DC disconnects; 690.53 operating current / operating voltage / maximum system voltage / short-circuit current on the DC disconnect; 690.54 rated AC output current and normal operating AC voltage at the point of interconnection (usually the main service); 705.10 / 690.56(B) directory at the electrical service and at the inverter; 690.17 'DO NOT TOUCH TERMINALS' on the DC disconnect and any equipment energised in the off position; 705.12(D)(7) 'WARNING: INVERTER OUTPUT CONNECTION DO NOT RELOCATE THIS OVERCURRENT DEVICE' at the inverter output OCPD; and 'WARNING: PHOTOVOLTAIC POWER SOURCE' on conduit, raceways and enclosures. The Standard Plan sheet 8 additionally shows a 'WARNING / DUAL POWER SOURCES / SECOND SOURCE IS PHOTOVOLTAIC SYSTEM' plaque and a 'PV SYSTEM AC DISCONNECT' plaque. 80% · published checklist
• Does the authority specify placard wording of its own? Yes. The city publishes specific placard wording of its own in the toolkit, e.g. 'WARNING: PHOTOVOLTAIC POWER SOURCE', 'PHOTOVOLTAIC SYSTEM DISCONNECT', 'WARNING! ELECTRIC SHOCK HAZARD. DO NOT TOUCH TERMINALS. TERMINALS ON BOTH THE LINE AND LOAD SIDES MAY BE ENERGIZED IN THE OPEN POSITION.', 'WARNING: INVERTER OUTPUT CONNECTION DO NOT RELOCATE THIS OVERCURRENT DEVICE', 'WARNING DUAL POWER SOURCES SECOND SOURCE IS PHOTOVOLTAIC SYSTEM RATED AC OUTPUT CURRENT ___ AMPS AC NORMAL OPERATING VOLTAGE ___ VOLTS' and 'PV SYSTEM AC DISCONNECT'. The wording is code-derived rather than invented locally, but it is published by the city as the text to use. 80% · published checklist
• Does it specify letter height, colour or material? Yes. For the photovoltaic power source markings: minimum 3/8 inch (9.5 mm) white letters on a red background, on reflective weather-resistant material, permanent and suitable for the environment. The Standard Plan adds an informational note that ANSI Z535.4 governs safety sign design, that a phenolic plaque with contrasting colours between text and background meets the intent of the code for permanency, and that although no type size is specified, 20 point (3/8 inch) should be considered the minimum. 85% · published checklist
• Is a site plan / facility map placard required, and what must it show? Yes. A permanent plaque or directory denoting all electric power sources on or in the premises is required (CEC 705.10), placed at the electrical service and also at the PV inverter if the inverter is not at the same location, providing the location of the service disconnecting means and of the photovoltaic system disconnecting means. Separately, the roof plan submitted with the application must show the panel layout, clear access pathways, approximate locations of the electrical disconnecting means and the roof access points. 80% · published checklist
• Does the UTILITY specify placards beyond the AHJ's? Yes. PG&E Electric Rule 21 section H.1.d ('Visible Disconnect Required') requires that where PG&E's operating practices call for an isolating switch, the device be clearly marked on the submitted single-line diagram with its type and location approved by PG&E before installation; if the device is NOT adjacent to the Point of Common Coupling, permanent signage must be installed at a PG&E-approved location giving a clear description of the device's location; and if the switch is not accessible outside locked premises, signage with contact information plus a PG&E-approved locking device for the premises must be installed. The switch itself must carry markings or signage clearly indicating open and closed positions. Generating facilities with non-islanding inverters totalling 1 kVA or less are exempt. 75% · utility DG manual
• Where must the labels be placed? On all interior and exterior DC conduit, enclosures, raceways, cable assemblies, junction boxes, combiner boxes and disconnects; markings on conduits, raceways and cable assemblies every 10 feet, within one foot of all turns or bends, and within one foot above and below all penetrations of roof/ceiling assemblies, walls and barriers; adjacent to the main service disconnect in a location clearly visible from where the disconnect is operated; on the AC and DC disconnects; at the utility-interactive inverter and battery enclosure; at the interactive point of interconnection (usually the main service); and at the inverter output overcurrent device. Where PV circuits are embedded in built-up, laminate or membrane roofing in roof areas not covered by modules, the circuit locations must be clearly marked on the roof. 85% · published checklist

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 city does not fix a location: the Solar PV Standard Plan shows the AC disconnect as 'Optional AC Disconnect per AHJ' and marks the Utility External Disconnect Switch as a yes/no item with the instruction 'Consult with your local AHJ and/or Utility'. PG&E's rule is the operative one: where PG&E's operating practices require it, the producer must furnish a ganged, manually-operated isolating switch NEAR THE POINT OF INTERCONNECTION that allows visible verification of separation (opening the enclosure to observe contact separation is acceptable), carries open/closed markings, can be reached quickly and conveniently 24 hours a day by PG&E personnel without keys, special permission or security clearances, and can be locked in the open position. No fixed distance from the meter is published. Non-islanding inverters totalling 1 kVA or less are exempt. 65% · utility DG manual
• Must equipment be on a specific approved list? No local approved-equipment list. Equipment must be listed and labelled and installed per the listing: DC PV modules listed to UL 1703, AC modules to UL 1703 and UL 1741, inverters to UL 1741 and marked 'utility interactive' for grid-connected systems, combiner boxes listed to UL 1741, DC-rated OCPDs and disconnects. Manufacturer specification sheets for inverters, modules, combiner/junction boxes and racking must be submitted, along with bonding and grounding installation instructions. 80% · published checklist
• Are batteries permitted, and under what conditions? Batteries are permitted, but NOT on the expedited/standard-plan route. The Eligibility Checklist requires the system to be 'utility interactive and without battery storage' and the Solar PV Standard Plan states it 'is not intended for bipolar systems, hybrid systems or systems that utilize storage batteries, charge controllers or trackers'. A PV-plus-storage job therefore goes through the standard permit process under the adopted CRC/CFC/CEC. Conversely, BMC 15.30.040 makes every NEW single-family residence of one or two dwelling units BESS-ready, requiring either a multi-mode BESS sized per CEC Article 710.15 or a 120/240 V, 125 A load centre on a 60 A feeder with spare 1 inch raceway. 75% · fire code + amendments
• Is there a separate ESS permit or inspection? No separate ESS permit type or ESS inspection is published. Storage is permitted under the same building/electrical permit and there is no ESS line in the fee schedule. 50% · portal
• Is a ground mount treated as a structure? Not addressed locally. A ground-mounted array falls outside BMC Ch. 15.56, which covers only systems 'installed on a single- or duplex-family dwelling' roof, and outside the Structural Criteria, which is for flush-mounted roof arrays. It would be permitted as a structure through the standard building permit process under the 2025 CBC/CRC. There is no zoning provision for ground-mounted solar in Title 17. 55% · ordinance
• Is there a local rule on service upgrades or busbar sizing? Yes, in practice through the Standard Plan rather than through an amendment: the expedited path requires a single-phase 120/240 Vac service panel with a busbar rating of 225 A or less, load-side connection only, and the inverter OCPD positioned at the opposite end of the busbar from the feeder, with the combined inverter and main OCPD checked against Table 5 (120% rule per CEC 705.12(D)(2)); reduction of the main breaker is not permitted under this plan. Anything outside that goes to the Comprehensive Standard Plan or a full submittal. Separately, BMC 15.30.040 requires new single-family dwellings to be BESS-ready with a 125 A load centre fed by a 60 A feeder. 75% · published checklist
• Is a specific mounting system or attachment spacing required? Yes. Structural Criteria Table 1 sets the maximum horizontal anchor spacing by roof slope and rafter spacing: flat to 6:12 gives 5 ft 4 in at 16 in o.c., 6 ft 0 in at 24 in o.c., 5 ft 4 in at 32 in o.c.; 7:12 to 24:12 gives 1 ft 4 in / 2 ft 0 in / 2 ft 8 in. Staggered anchors may double the spacing to a maximum 6 ft 0 in; plated wood trusses at flat to 6:12 are capped at 4 ft 0 in with staggered adjacent rows. Fasteners: 5/16 in diameter lag screws with 2.5 in embedment into the rafter, or the anchor manufacturer's guidelines. Array must be flush-mounted parallel to the roof with a 2 to 10 in gap, must not overhang ridges, hips, gable ends or eaves, must not exceed 4 psf (PV), and must not cover more than half the total roof area. Manufacturer worksheets, tables or calculator output must be attached. 90% · 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. Inspections are requested through the Clariti customer portal, for which the city publishes 'Scheduling Inspections' training videos. The 2018 Submittal Requirements Bulletin also gives a phone line, 661-326-4677, and a Click2Gov URL that is now dead. 70% · department page
• How much notice is required? Effectively one business day: 'Inspection requests received within business hours are scheduled for the next business day.' Office hours are 8 a.m. to 5 p.m. Monday to Friday except holidays. 60% · published checklist
• Are same-day or AM/PM windows offered? Not published. The only published statement about timing is next-business-day scheduling of requests received during business hours; the city publishes no AM/PM window, no same-day option and no time-slot arrangement. 50% · 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. City staff perform the inspection, and for an eligible expedited system there is ONE inspection. 90% · ordinance
• If delegated, to whom? Not delegated - the City of Bakersfield Building Division inspects. No third-party or county inspection agency is involved. 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 inspection - a single final - for an eligible expedited small residential rooftop system. Exception for TILE ROOFS, which must be inspected by one of two methods: (1) a solar installation employee is at the job site to meet the building inspector and uncover roof tiles to expose roof flashings as requested, or (2) the inspection is done in two parts, first a roof flashing inspection and then a final inspection. If the system fails, a subsequent inspection is authorised and need not conform to the one-inspection rule. 90% · ordinance
• Is a rough-in or mid-roof inspection required? No for composition and comparable roofs - one inspection only. Yes, effectively, for TILE roofs, where the applicant may elect a separate roof-flashing inspection before the final (the alternative being to have an installer on site to lift tiles for the inspector). 80% · 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. 'Inspection Guide for PV Systems (For Rooftop Photovoltaic Systems meeting the Standard Plan)', PV Toolkit Document 7, 8 pages, published on the Building Division Forms page under 'Expedited Residential Solar Installation'. It has a one-page Section 1 field inspection guide (19 items) and a Section 2 comprehensive reference covering general, electrical, bonding/grounding, conductor management, overcurrent protection, connections, disconnects, inverters, signs and labels, and fire safety. 92% · department page
• What must be on site at inspection? The approved plans (the inspector checks module model and quantity, array mounting and structural connections, roof penetrations, conduit, conductors, OCPDs, disconnects and labels 'according to the approved plan'), and the permit holder must be prepared to show conformance with all technical requirements in the field. Manufacturer specification sheets are the reference for module model numbers and for bonding/grounding hardware. Building Division practice elsewhere uses a job card (the refund provision at BMC 15.05.050 requires 'the approved plans and job card' to be returned), and the Fire Department's own guidance is 'Do not perform work without a Fire Department job card on site'. 55% · published checklist
• Does the inspector verify labels and listings? Yes. The inspector verifies both labels and listings: 'Equipment installed, listed and labeled according to the approved plan (e.g., PV modules, DC/DC converters, combiners, inverters, disconnects, load centers and electrical service equipment)' and 'PV system markings, labels and signs according to the approved plan'; the Submittal Requirements Bulletin lists 'Appropriate signs are property constructed, installed and displayed' and equipment ratings consistent with the installed signs. 90% · published checklist

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 passed final inspection on the permit. No certificate of occupancy is issued for a solar retrofit; the city's Temporary Certificate of Occupancy fee line applies to buildings, not to PV. Nothing described as a green tag or a separate letter is published. 65% · department page
• Who notifies the utility for PTO? Installer. The final electrical inspection clearance from the city has to be submitted into PG&E's interconnection application, after which PG&E issues the Permission to Operate letter. The city does not notify PG&E. 65% · utility DG manual
• Is there a re-inspection fee? $99 per hour with a 2-hour minimum during normal business hours (so $198 minimum); actual cost per hour based on the salary schedule outside normal business hours. (Grading re-inspection is separately $90 per hour.) 80% · fee schedule
• How are corrections issued and cleared? On an incomplete application the building official issues a WRITTEN CORRECTION NOTICE detailing all deficiencies and any additional information required to be eligible for expedited permit issuance. If the system fails inspection, a subsequent inspection is authorised (and is not bound by the one-inspection rule), charged at the re-inspection rate. 70% · ordinance