City of Santa Rosa

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 - within the incorporated City of Santa Rosa 96% · adopting ordinance
• What does this authority permit itself, and what does it delegate? Both - building and electrical are held by the Building Division of the Planning & Economic Development Department. The Fire Department holds the ESS/battery fire construction permit and a separate PV/ESS fire final. 92% · department page
• 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 90% · ordinance
• Is a HOA or architectural approval required first? No. The City does not condition a solar permit on HOA or architectural approval, and neither Ch. 18-68 nor the PV submittal checklist mentions an association. 80% · ordinance
• Is there a historic-district review? No City historic review for the panels themselves. SRCC 20-58.060(A)(2)(j) exempts 'Solar panels, and integral parts of the solar panel system including supporting posts or poles' from the Landmark Alteration Permit requirement in a Preservation District or on a designated landmark, provided the project is consistent with the Secretary of the Interior's Standards; new structures built in conjunction with a system (a carport or similar) are NOT exempt. SRCC 20-52.030 carries the identical exemption from Design Review. In both sections the same rider applies: if the panels could create a life or safety issue such as excessive glare to local residences, sensitive facilities (airport) or water resources, a Minor Use Permit or Conditional Use Permit is required depending on severity. 91% · ordinance
• Is a wind or windstorm certification required? No. California has no windstorm certification regime of the Texas TDI kind. What the City does require is that the wind exposure category (B, C or D) be specified on the plans and calculations wherever structural calculations are triggered, and that the wind load to the worst-case anchor be calculated. 85% · published checklist
• Is a Specific Use Permit or Council approval ever required? Not normally. Rooftop PV is administratively approved. Two discretionary hooks exist and both turn on the same test: SRCC 18-68.030(C) and 18-68.060(A) let the Building Official require a Minor Use Permit where a small residential rooftop system 'would have a specific, adverse impact upon the public health or safety including excessive glare to local residents, negative impacts to sensitive facilities (airports) or water resources'; SRCC 20-52.030 and 20-58.060 impose a Minor Use Permit or Conditional Use Permit on the same glare/sensitive-facility/water-resource grounds. Denial requires written findings on substantial evidence that there is no feasible mitigation, and any condition must be designed to mitigate at the lowest possible cost. Appeals go to the Planning Commission. No City Council approval is contemplated. 90% · ordinance
• Is there a system-size cap on residential generation? No cap on residential generation. 10 kW AC nameplate (or 30 kW thermal) is the ceiling for the EXPEDITED route only: SRCC 18-68.020 defines a 'small residential rooftop solar energy system' as no larger than 10 kW AC, on a single- or duplex-family dwelling roof, conforming to State and City codes as amended, with an array not exceeding the maximum legal building height in the Zoning Code. Anything above that, or a ground mount, falls out of the expedited process into standard permit requirements (18-68.050(E)) but is not prohibited. SolarAPP+ applies its own separate eligibility limits. 90% · 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? Licensed contractor (C-46 solar or C-10 electrical) or homeowner as owner-builder 90% · ordinance
• Must the contractor be registered with this authority before applying? Yes - an active City of Santa Rosa business licence is required, though at issuance rather than at application 85% · department page
• Is a homeowner permitted to self-install and self-permit? Yes 88% · 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? Per the City's PV System Submittal Checklist (last updated 5 May 2026): (1) general information and building data on the reverse of the handout; (2) a general site plan showing locations of proposed PV panels, system equipment, electrical panels, disconnects, ESS, alarms and stickers/signage; (3) a dimensioned plan of racking/anchorage layout with required fire setbacks and walking aisles to/at ridges and under emergency escape and rescue openings (CRC R329.6); (4) attachment/anchorage details to the existing framing; (5) a single-line diagram showing panel busbar ratings, breaker sizes, wire sizes/types/lengths, PCS types, ESS types, generator types, interconnection methods, rapid-shutdown compliance and grounding; (6) the proposed interconnection method at each panel (CEC 705.11, 705.12(A), 705.12(B)(1-6), 705.13); (7) permanent stickers/signage and their locations for disconnects, 120%-rule circuit breakers and site-specific plaques (CEC 705.10, 705.23(B)); (8) listings for every element (panels, inverters, optimisers, PCS, gateways, ESS, disconnects, rapid-shutdown devices); (9) listings showing the panel and racking system together create a Class A fire rating - flagged as a LOCAL requirement for all of Santa Rosa; (10) for ESS in a garage, the smoke-alarm listing for garage use. Structural calculations where triggered. Via SolarAPP+ the approved SolarAPP+ plan set replaces the drawing package. 93% · published checklist
• How many copies, and in what format? Electronic only in normal practice: PDF, each form as its own separate PDF file, plans as one complete set, submitted through the Accela Citizen Access portal / Digital Plan Room. Where paper is used at an in-person appointment it must be brought on a thumb drive in PDF; the residential drawing standard is a complete set at 24 in x 36 in minimum sheet size (smaller allowed only if the Chief Building Official or designee permits). Under SolarAPP+ the approved SolarAPP+ documents, the building permit and the inspection card must be printed and available on site. 88% · department page
• Is a site plan required, and what must it show? Yes. A general site plan showing the locations of the proposed PV panels, system equipment, electrical panels, disconnects, ESS, alarms and stickers/signage; plus a separate dimensioned plan of the racking/anchorage layout showing the required fire setbacks and walking aisles to and at ridges and under emergency escape and rescue openings (CRC R329.6). Zoning data on the cover (APN, zoning, site area). For a ground mount, the residential plot-plan checklist calls out 'Free standing photovoltaic systems' as an item that must appear on the plot plan. 92% · published checklist
• Is a one-line / three-line diagram required? Yes - a single-line diagram is required 94% · published checklist
• Are string and conductor calculations required? No separate string or conductor calculation package is required; the values must instead appear on the single-line diagram (wire sizes, types and lengths, busbar ratings, breaker sizes) and the interconnection method must be identified by CEC section. Structural calculations, by contrast, are required at the thresholds in Q13. 72% · published checklist
• Is a structural PE stamp required, and at what threshold? Yes, at defined thresholds. Structural calculations by a California licensed architect, civil engineer or structural engineer are required if any of the following apply: racking/PV anchorage into plywood decking only; anchorage clamped to standing-seam metal decking; a ballasted system; roof framing members smaller than 2x4; framing spaced greater than 24 in o.c.; PV panels weighing more than 20 psf; anchorage spaced more than 72 in on centre; the array mounted higher than 30 ft above adjacent grade; the structure/array within 5,000 ft of a lake; mechanical/electrical equipment (ESS, inverter, generator) over 400 lb; existing framing not wood; or any ground-mount system. Deep foundations on a ground mount additionally require a geotechnical report stamped by a California licensed geotechnical or civil engineer. There is an explicit exemption for anchors into plywood decking only where ALL of: mean roof height no more than 25 ft; decking at least 7/16 in OSB or 15/32 in plywood (24/16 rated); supporting framing no more than 24 in o.c.; height from roof surface to top of modules no more than 5.25 in; minimum 12 in setback from roof edges; maximum tributary wind uplift area per anchor 10.57 sq ft; and the anchor listed for plywood-only anchorage with a minimum wind uplift capacity of 210 lb allowable. 93% · published checklist
• Is an electrical PE stamp required, and at what threshold? No electrical PE stamp is required at any threshold for residential PV. The only stamp the City demands is the structural one, and it may come from a licensed architect, civil engineer or structural engineer. 80% · 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? Accela Citizen Access, branded 'Permit Santa Rosa', with a Digital Plan Room for plan submittal and review. The current entry point is https://santarosa-prod.accela.com/portal/core/index; an older Accela host, https://aca-prod.accela.com/santarosa/Default.aspx, is still linked from several City pages including the Solar Panel Installation page and the Fire plan-review page. For eligible residential rooftop PV the City also uses SolarAPP+ (gosolarapp.org) for automated plan review, with the approval ID then entered into Accela. 90% · portal landing page
• Can the whole application be completed online? Yes 92% · portal
• What does a residential solar permit cost? $400.74 in Building Division fees for a residential roof-mounted system ($100.18 plan check + $300.56 inspection), before surcharges. A technology surcharge of 5.69% applies to all building fees and an advance-planning surcharge of 12.26% applies to non-trade building and plan-review fees, which if both are applied takes the total to roughly $473. A battery adds $187.85 (Energy Storage System electrical permit line) plus a Fire Department battery-system plan review and inspection fee of $394. Ground mounts: $601.13 + $801.50 (pedestal) or $1,001.88 + $1,001.88 (structure). SolarAPP+ charges its own processing fee direct to the installer, on top. 86% · fee schedule
• How is the fee calculated? Flat - a fixed plan-check unit fee and a fixed inspection unit fee per system, banded by mount type (residential roof, commercial roof, ground-mount pedestal, ground-mount structure). Not valuation-based and not per kW or per panel. Percentage surcharges are then applied on top of the flat fees. 90% · fee schedule
• Is there a separate plan-check fee? Yes - $100.18 plan-check fee for a residential roof-mounted PV system, separate from the $300.56 inspection fee 92% · 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? 3 business days for PV plans with no energy storage system; 14 days where an ESS is included. Under SolarAPP+ the permit issues immediately on upload of the approved SolarAPP+ documents. SRCC 18-68.060(G) independently requires a nondiscretionary small residential rooftop solar application to be reviewed and approved or rejected within three business days, and resubmittals likewise. 92% · department page
• How long is an issued permit valid before it expires? 365 days. A permit becomes invalid unless work is commenced within 365 days of issuance, or if work is suspended or abandoned for 365 days after commencement. The Building Official may grant a 180-day extension on written request showing circumstances beyond the applicant's control, and a further 180 days where the applicant is diligently pursuing completion; no extension may be granted if no work has begun and no inspection has been approved within three years of issuance. Separately, an application and plan review expire if no permit is issued within one year of filing, extendable by 180 days. 93% · ordinance
• Which utility handles interconnection here? Pacific Gas and Electric Company (PG&E). Sonoma Clean Power is the community choice aggregator for Santa Rosa and supplies generation only - it does NOT run interconnection, does not issue permission to operate, and has no disconnect, placard or metering requirements of its own. 94% · department policy
• Where does the utility sit in the sequence? Parallel, with one hard dependency at the end. The contractor files the PG&E interconnection application early and independently of the City permit; the City permit and inspection proceed on their own track; but PG&E will not grant permission to operate until it receives a copy of the FINAL building permit alongside the interconnection application and single-line diagram. SRCC 18-68.060(H) states expressly that City approval 'does not authorize an applicant to connect ... to the local utility provider's electricity grid' and that obtaining that permission is the applicant's responsibility. 91% · 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, as the 2025 California Electrical Code (Title 24 Part 3), in force since 1 January 2026 95% · adopting ordinance
• Which building code edition is in force? 2025 California Building Code and 2025 California Residential Code (Title 24 Parts 2 and 2.5), plus the 2025 California Existing Building Code, Energy Code, CALGreen, Historical Building Code and - listed separately - the 2025 California Wildland-Urban Interface Code (Part 7). The International Property Maintenance Code 2024 is also adopted. Adopted by Ord. 2026-001, 13 January 2026. 94% · adopting ordinance
• Which fire code edition is in force? 2025 California Fire Code (Title 24 Part 9), including Appendix Chapters 4, B, BB, C, CC, D, E, F, G, H, I, N, P and Q, adopted as the Fire Code of the City of Santa Rosa by Ordinance No. 2025-017 on 18 November 2025 under H&SC 13869 94% · adopting ordinance
• Are there local amendments to any of the above? Yes - four separate local amendment packages are attached to Title 18: 2025 CBC Amendments (20 pp), 2025 CRC Amendments (7 pp), 2025 CEC Amendments (1 p) and 2025 CFC Amendments (32 pp). Two of them reach rooftop PV directly. SRCC 18-22R902.4 amends CRC R902.4 to add: 'Class A photovoltaic panel systems and modules shall be installed in all areas, in jurisdictions designated by law as requiring their use.' SRCC 18-22R902.1 and 18-16.1505.1 require minimum Class A roof assemblies city-wide (not merely in the VHFHSZ), and 18-22R902.1.1 / 18-16.1505.1.1 extend that to the entire roof covering of every existing structure where more than 50 percent of the roof area is replaced in any one year. The 2025 CEC amendments touch only permit expiration, the appeals board, a penalty provision and four deleted H80 sections - nothing on Article 690 or 705. 93% · local amendments
• What is the installation judged against? The 2025 California Electrical Code (2023 NEC) as adopted at SRCC 18-04.015 and renumbered at 18-32, together with the City's four amendment packages, and read alongside the Building Division's own handouts: the PV System Submittal Checklist, 'Interconnected Power Sources' (CEC 705.12) and 'Power Control Systems' (CEC 705.13). CRC R329 governs the PV-specific building requirements and CRC R330 the ESS requirements. The checklist's own definition is explicit: 'CALIFORNIA ELECTRICAL CODE (CEC): THE ELECTRICAL CODE ADOPTED LOCALLY, COMPLETE WITH CITY OF SANTA ROSA AMENDMENTS.' 90% · 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? The state provisions apply unamended: 2025 CRC R329.6 / 2025 CFC 1205. Not fewer than two pathways not less than 36 in wide, on separate roof planes, from lowest roof edge to ridge, on all buildings, with at least one on the street or driveway side; and for each roof plane carrying an array, a 36 in pathway from lowest roof edge to ridge on that plane, an adjacent plane, or straddling both. Ridge setback: 18 in clear on both sides of a horizontal ridge where the array occupies no more than 33 percent of plan-view roof area, 36 in where it exceeds 33 percent - but where the dwelling has an NFPA 13D sprinkler system the thresholds relax to 18 in up to 66 percent coverage and 36 in above 66 percent. No panels below an emergency escape and rescue opening, with a 36 in pathway to it. Requirements do not apply to roof slopes of 2:12 or less, nor to detached non-habitable structures. Santa Rosa detail that changes the arithmetic: SRCC 18-22R309.2 as amended requires an automatic residential sprinkler system in ALL Group R-3 occupancies regardless of square footage, and 18-22R309.2.2/.2.3/.2.4 extend that to substantial remodels, additions and alterations - so on a new or rebuilt Santa Rosa house the relaxed 66 percent alternative setback is normally the one in play. 86% · 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? Yes - rapid shutdown to NEC 690.12 as adopted in the 2025 California Electrical Code (2023 NEC), with no local amendment. The City makes it a submittal item twice over: the single-line diagram must show 'RAPID SHUTDOWN COMPLIANCE', and listings must be provided for the rapid-shutdown devices themselves. 90% · published checklist

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? Three overlapping sets. (1) City/CEC: permanent stickers and signage, with their locations shown on the plans, for the disconnects, for 120%-rule circuit breakers, and the site-specific plaque - the checklist cites CEC 705.10 and 705.23(B). ESS disconnects must be permanently marked 'ENERGY STORAGE SYSTEM DISCONNECT' (CEC Article 706). (2) Santa Rosa Fire Department, from its residential ESS bulletin: a permanent plaque or directory denoting all electrical sources on or in the premises, installed at each service equipment location and at the location of every electric power production source capable of being interconnected, or at an approved readily visible location, marked 'CAUTION: MULTIPLE SOURCES OF POWER', with any posted diagram correctly oriented to its own location; plus placards or directories at every disconnecting means giving the location of all the others, all field-marked legibly. (3) PG&E, independent of the AHJ: permanent signage affixed to the meter panel indicating an alternative source of generation is interconnected; signage AND a map at the meter panel where the AC disconnect is more than 10 ft away and out of line of sight; and for a supply-side connection, an engraved placard on the metering equipment indicating there is a line/supply-side connection. 87% · fire department standard
• Does the authority specify placard wording of its own? Yes, but thinly, and the only genuinely local wording sits on an expired sheet. The Fire Department bulletin specifies the caption 'CAUTION: MULTIPLE SOURCES OF POWER' for the all-sources plaque and 'ENERGY STORAGE SYSTEM DISCONNECT' for the ESS disconnect - both reproduce state ESS/NEC provisions rather than inventing wording. The one piece of wording no code section carries is on the Residential Rooftop Photovoltaic REACO Checklist, still posted on the City's Building Forms and Building Design Assistance pages: 'Microinverter systems must have label on the exterior of the main service panel stating "Microinverter System Solar Breaker inside Panel is PV System Disconnect"'. That handout states its own effective period as 1 January 2014 through 31 December 2016 and certifies compliance with the 2013 Title 24, so it is expired by its own terms while remaining published. 78% · published checklist (expired)
• Does it specify letter height, colour or material? Nothing current from the City. No letter height, colour or material specification appears in the 5 May 2026 PV System Submittal Checklist, in Ch. 18-68, or in any of the four 2025 code amendment packages. Two documents do carry specifications and both need labelling as to their status. (a) The expired REACO Checklist, still posted: 'Permanent labels and signage with a red background and white lettering resistant to fading pursuant to UL 969 and California Electrical Code Article 690 and permanently affixed'; and 'All roof surface mounted conduits, pipes, braces, etc. crossing the pathways are to be clearly identified by a red/white reflective tape, or other approved identifying material.' (b) PG&E's Greenbook, current and binding on the meter panel: acceptable labelling is an identification plate attached by screws, rivets or weatherproof adhesive (with a UV protection rating for outdoor meters), or paint that cannot be removed with common solvents applied through a stencil, or - indoors only - manufactured decals that will not peel or fade; tape-type and label-maker stick-on labels and hand-written lettering (sharpie, paint stick) are expressly 'Unacceptable for Permanent Installation'. PG&E also uses the word 'engraved' for the supply-side placard. No letter height is stated by anyone in this jurisdiction. 84% · published checklist (expired) + utility manual
• Is a site plan / facility map placard required, and what must it show? Yes. The City requires the site-specific plaque as a submittal item - 'SPECIFY PERMANENT STICKERS/SIGNAGE (AND LOCATIONS) FOR DISCONNECTS, 120% RULE CIRCUIT BREAKERS, SITE-SPECIFIC, ETC. - SEE CEC 705.10, 705.23(B)' - and the general site plan must itself show the locations of PV panels, system equipment, electrical panels, disconnects, ESS, alarms and stickers/signage. The Fire Department bulletin sets what the plaque must convey: all electrical sources on or in the premises, at each service equipment location and at each interconnectable power production source, headed 'CAUTION: MULTIPLE SOURCES OF POWER', with any posted diagram 'correctly oriented with respect to the diagram's location'. PG&E adds a genuine map requirement at the meter panel where the AC disconnect is both more than 10 ft away and out of line of sight. 86% · published checklist
• Does the UTILITY specify placards beyond the AHJ's? Yes - PG&E, in the Greenbook, and this is independent of anything the City requires. Verbatim: 'Customers who install distributed generation (e.g., solar, wind, battery storage) that is connected to the electric meter panel are required to install permanent signage affixed to the panel indicating an alternative source of generation is interconnected. If applicants intend to interconnect their generation facilities to PG&E's power system, they must refer to the PG&E Distribution Interconnection Handbook. Signage and maps also are required at the meter panel for the alternating current (ac) disconnect switch location when it is more than 10 feet away and out of the line of sight from the meter panel.' Separately, for a supply-side connection: a fusible AC disconnect switch is required ahead of the main breaker and after the meter, and 'Also required is an engraved placard (signage), indicating there is a line/supply side connection, installed on the metering equipment.' Sonoma Clean Power, being generation-only, specifies nothing. 92% · utility DG manual
• Where must the labels be placed? At the disconnects and at the 120%-rule circuit breakers, and wherever the site-specific plaque is required, with all of those locations drawn on the submitted site plan (City). At each service equipment location and at the location of every electric power production source capable of being interconnected, or another approved readily visible location, for the all-sources plaque; and at every disconnecting means where they are out of sight of each other, each carrying the locations of the others (Fire Department). Affixed to the electric meter panel for the DG signage, with the added map at the meter panel where the AC disconnect is more than 10 ft away and out of line of sight; and on the metering equipment for the engraved supply-side placard (PG&E). ESS disconnects: readily accessible, within sight of and within 10 ft of the ESS, permanently marked. 86% · 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? PG&E states no distance for the PV AC disconnect. Greenbook Table 6-3 goes further and exempts the commonest residential case entirely: for INVERTER-BASED generators on a self-contained, socket-based meter panel of 320 amps or less continuous current rating, single phase, an AC disconnect is 'No' - not required. All other self-contained or transformer-rated meter panels, and all non-inverter-based generators, require one; and 'An ac disconnect is required for all K-base meter panels of any ampacity rating.' If one is installed it must be PG&E approved. The ten feet that does appear is a signage trigger, not a location limit: 'Signage and maps also are required at the meter panel for the alternating current (ac) disconnect switch location when it is more than 10 feet away and out of the line of sight from the meter panel.' Separate and distinct 10-ft rules in the same manual apply to the MAIN SERVICE disconnect (section 7.8: 'Applicants must place the main service disconnect switch adjacent to the meter(s), not more than 10 feet away and within line of sight') and to metering equipment relative to the service disconnecting means (section 7.5) - neither is about the PV disconnect. For a supply-side connection a fusible AC disconnect ahead of the main breaker and after the meter is required, plus an engraved placard on the metering equipment. Santa Rosa itself sets no distance; the only 10-ft requirement the City enforces is the ESS disconnect within sight and within 10 ft of the ESS under CEC Article 706. 93% · utility DG manual
• Must equipment be on a specific approved list? No proprietary approved-product list. Equipment must be listed and labelled to named standards: residential PV panels and modules to UL 1703 or to both UL 61730-1 and UL 61730-2 (CRC R329.3.1); residential inverters to UL 1741 (CRC R329.3.1); residential ESS to UL 9540 (CRC R330.2), with UL 1973 and 9540A test reports where applicable; and the panel-and-racking system listings must together show a Class A fire rating, which the City flags as a local requirement for all of Santa Rosa (SRCC 18-22R902.1, 18-16.1505.1; and SRCC 18-22R902.4 requires Class A PV panel systems and modules, tested to UL 1703 and UL 2703). The Fire Department bulletin adds that 'ESS listed and labeled solely for utility or commercial use shall not be used for residential applications.' One utility-side exception is a genuine approval: PG&E's Greenbook Table 6-3 note 2 states that if an AC disconnect switch is installed it 'must be PG&E approved'. 88% · published checklist
• Are batteries permitted, and under what conditions? Yes, with a detailed local overlay. SRCC 18-44.1207.11 as amended requires ESS in Group R-3 and R-4 to comply with CFC 1207.11.1 through 1207.11.10, and SRCC 18-44.1207.11.10 ADDS an emergency electrical disconnect provision: where access to ESS main electrical control panels requires entry to or passage through parts of a structure that may be involved with fire, smoke, gases or hazardous materials, or otherwise unsafe for emergency personnel, 'the chief may require that a means of remotely disconnecting electrical service to the structure be provided ... by a physical disconnect approved by the fire department.' The Fire Department's residential ESS bulletin then sets the conditions: permitted locations are detached garages and detached accessory structures; attached garages separated per CRC R302.6; outdoors or on the exterior side of exterior walls not less than 3 ft from doors and windows directly entering the dwelling; and enclosed utility closets, basements, storage or utility spaces with finished or noncombustible walls and ceilings (unfinished wood-framed walls to get not less than 5/8 in Type X gypsum). Not in sleeping rooms, closets, spaces opening directly into sleeping rooms, or habitable spaces. Individual units maximum 20 kWh; aggregate 40 kWh in utility closets and storage/utility spaces, 80 kWh in attached or detached garages and detached accessory structures, 80 kWh on exterior walls, 80 kWh outdoors on the ground. Units separated by at least 3 ft unless UL 9540A large-scale fire testing justifies less. Smoke alarms per CRC R314, or a listed heat detector where a smoke alarm cannot be listed for the location. Impact protection by approved barriers where subject to vehicle damage. Ventilation and gas-detection requirements for batteries that produce hydrogen. ESS with potential to release toxic or highly toxic gas are prohibited in R-3 and R-4. 90% · fire code + amendments
• Is there a separate ESS permit or inspection? Yes, on both sides. Building: an 'Energy Storage System' electrical permit fee line of $187.85 sits in the fee schedule separate from the PV line, and PV plans with an ESS get 14 days of plan review instead of 3. Fire: 'For residential Group R-3 and R-4 Occupancies a fire construction permit in accordance with this informational bulletin and CFC 105.7.2 is required for all ESS systems exceeding 1.00 kWh', and there is a dedicated inspection, Selectron code 727 'PV or ESS FIRE FINAL', schedulable through Selectron or direct with the Fire Department on (707) 543-3500. 88% · fee schedule + fire department standard
• Is a ground mount treated as a structure? Yes by the Building Division, though the Zoning Code is silent. Ground mounts carry their own fee lines - Ground Mount Pedestal $601.13 plan check + $801.50 inspection, Ground Mount Structure $1,001.88 + $1,001.88 - which are two to three times the roof-mount fee. Structural calculations are mandatory for every ground-mount system, and a geotechnical report stamped by a California licensed geotechnical or civil engineer is required if deep foundations are used. Ground mounts are excluded from the SolarAPP+ instant route and, being outside the 'small residential rooftop' definition, from the SRCC 18-68 expedited process. The residential plot-plan checklist lists 'Free standing photovoltaic systems' as an item to be shown. The state code that applies unamended adds a defensible-space rule that matters in Santa Rosa: CRC R329.8.2 - setback requirements do not apply to ground-mounted free-standing arrays, but 'A clear, brush-free area of 10 feet (3048 mm) shall be required for ground-mounted photovoltaic arrays'; and R329.8.1 leaves fire separation distance to the enforcing agency. 86% · fee schedule + ordinance
• Is there a local rule on service upgrades or busbar sizing? Yes, on two fronts. (a) Busbar and interconnection: the Building Division publishes an 'Interconnected Power Sources' handout giving the load-side interconnection options in the City's own notation - main panel Option 1: T > U+V; Option 2: 1.2T > U+V (the 120% rule); Option 3: T > the sum of the main panel breakers minus U, where T is the busbar rating, U the main breaker and V the back-fed breaker - with the parallel set for sub panels (W > V+X, 1.2W > V+X, W > sum of subpanel breakers minus V), a note that one back-fed breaker may be installed at the opposite end from the supply, and a note that a breaker at either end is acceptable and both are not needed. A companion 'Power Control Systems' handout covers CEC 705.13. The PV checklist's number-one 'common issue during review' is an incorrectly specified interconnection method, and it asks installers to name the CEC subsection at each interconnection point. (b) Service/meter panel replacement: Building Division Policy 3.5.11 (eff. 5 March 2024) governs like-for-like replacement of unsafe panels under PG&E's gas-meter setback variance - the City will accept a C-10 electrician's (or Electrical Engineer's) written inspection and unsafe-conditions statement on letterhead with the licence number, uploaded with the application, and on permit issuance the City provides the letter PG&E requires; the panel must then be replaced or decommissioned within 90 days of approval/permit issuance. 88% · department handout
• Is a specific mounting system or attachment spacing required? Yes - the City sets attachment and spacing conditions rather than naming a product. Anchorage to plywood decking only is permitted without calculations only where the anchor is listed for plywood-only anchorage with a minimum wind uplift capacity of 210 lb (allowable load level), decking is at least 7/16 in OSB or 15/32 in plywood (24/16 rated), supporting framing is no more than 24 in o.c., the installed height from roof surface to top of modules is no more than 5.25 in, the setback from roof edges is at least 12 in, mean roof height is no more than 25 ft, and the tributary wind uplift area per anchor is no more than 10.57 sq ft. Anchorage spaced more than 72 in on centre triggers full calculations, as does clamping to standing-seam metal decking or any ballasted system. The panel-and-racking listing must together produce a Class A fire rating. The 8 Jan 2026 reroof policy requires the anchorage spacing and anchorage type/detail to be shown on plans even where panels are removed and returned to the same position. 91% · 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, phone, text or in-office call - four routes, all City-run. Accela Citizen Access online (approved registration required); the Selectron automated voice line on (707) 543-3006; text 'MENU' or any keyword to (833) 692-5526; or call the office on (707) 543-3200 option 1. Fire finals for PV or ESS (code 727) can be booked through Selectron or direct with the Fire Department on (707) 543-3500. 92% · department page
• How much notice is required? One business day, with a hard 2:30 pm cut-off the day before. 'The deadline for calling the automated inspection request phone line to schedule an inspection for the next day is 2:30 p.m. the day before the inspection is desired. NEXT-DAY INSPECTIONS WILL NOT BE PROVIDED IF THE SCHEDULE IS FULL.' The same 2:30 pm deadline applies to the online and phone routes. Cancellations must be in by 11:59 pm the day before. Selectron will schedule up to five business days out and the Department recommends booking a week ahead; inspections may roll to another day if the calendar is full. 92% · department page
• Are same-day or AM/PM windows offered? No same-day service and no bookable AM/PM windows. 'Specific times of the day cannot be scheduled.' A two-hour window is given on the morning of the inspection: the on-site contact is called between 7:30 am and 8:30 am and told both the window and whether the inspection will be in person or remote. Applicants are advised to call (707) 543-3200 on the morning of the inspection to confirm the time frame. 90% · 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 City's own Building Division inspectors, with two wrinkles. Solar and ESS (code 160) is on the published list of inspections eligible for a Remote Building Inspection, conducted over FaceTime or Zoom or by photographic evidence; the determination is the inspector's, not the applicant's, and is communicated on the morning of the inspection. Separately, an applicant may elect Third Party Plan Review and Inspection Services (TPPRIS) from the City's approved-agency list, but only with pre-approval by the Chief Building Official, at the applicant's own cost, and expressly as a voluntary alternative rather than a delegation. The PV or ESS fire final (code 727) is the Fire Department's. 90% · department page
• If delegated, to whom? Not delegated. Where an applicant elects TPPRIS, the City's published approved third-party plan review and inspection agencies include 4 Leaf Inc. (Fair Oaks), Ballard and Watkins Construction Services (San Anselmo), Bureau Veritas North America (Santa Rosa office at 111 Santa Rosa Avenue Suite 406) and Coastland Civil Engineering (Santa Rosa), among others on the list. The Chief Building Official must approve the arrangement and may reduce City plan review or inspection fees by a stated percentage; City fees are otherwise still payable and the applicant pays the third party directly. 85% · department policy

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 system, one inspection. SRCC 18-68.060(I): 'Only one small residential rooftop solar energy system inspection shall be required and performed by the Building Official or qualified designee.' In the Selectron code set that is code 160, SOLAR PANELS/PV SYSTEMS (listed as 'Solar and ESS' on the RBI page), followed by 195 PERMIT FINAL. Where a battery is installed, add code 727 PV or ESS FIRE FINAL, from the Fire Department. Where the work includes a service or meter panel change, add 181 ELECTRIC METER RELEASE. Codes 189 FINAL BUILDING, 190 FINAL ELECTRICAL, 191 FINAL PLUMBING, 192 FINAL MECHANICAL and 402 FINAL COMBO exist for larger scopes. Code 140 SOLAR PLUMBING covers solar thermal. 88% · ordinance + department page
• Is a rough-in or mid-roof inspection required? No, not for a retrofit rooftop PV system - the ordinance limits it to a single inspection. A mid-roof or in-progress reroof inspection (code 126 REROOF) applies where the PV work is bundled into a reroof permit, which since 8 January 2026 is the required route where panels are removed and replaced as part of re-roofing. 82% · 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 published inspection checklist for solar. The City publishes a plan-review checklist (the PV System Submittal Checklist) and a list of 'Common Issues During Review', but nothing describing what is checked in the field. 80% · department page
• What must be on site at inspection? Printed approved SolarAPP+ documents, the building permit and the inspection card, all available on site. For a conventionally reviewed permit, an approved copy of the plans must be kept at the job site. For a remote inspection, the approved construction plans must be shown on request and supporting documents (job inspection card, structural observation reports, special inspection reports, HERS reports) emailed to the inspector beforehand; the video or photo inspection must begin at the street with the property address clearly visible, and the on-site contact must be knowledgeable about the trade - normally the responsible contractor or the owner-builder. 88% · department page
• Does the inspector verify labels and listings? Yes. The Solar Panel Installation page states of the SolarAPP+ route that 'Approved SolarApp+ documents, the Building Permit, and Inspection Card must be printed and be available on-site for inspection. Inspectors will verify the approved project documents in the field.' The submittal checklist requires the signage and its locations, and the listings for every component, to be on the approved plans, which is what the inspector then checks against. Under a remote inspection, 'Approved construction plans must be available and shown upon request.' 85% · department page

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? A final on the permit - the building inspector 'finals the permit'. No certificate of occupancy is issued for a PV permit: 'CERTIFICATES OF OCCUPANCY ARE NOT PROVIDED FOR PERMITS WITH LIMITED SCOPE THAT DO NOT RESULT IN OCCUPIABLE SPACE.' The relevant Selectron result codes are 160 (solar/PV inspection) and 195 PERMIT FINAL, with 181 ELECTRIC METER RELEASE where the meter panel was touched. Final inspections cannot be scheduled until all invoiced fees have been paid. 87% · department page
• Who notifies the utility for PTO? Installer. SRCC 18-68.060(H) is explicit that administrative approval by the Building Official 'does not authorize an applicant to connect the small residential rooftop 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.' PG&E's own process puts the contractor in that seat: the contractor submits the interconnection application, the single-line diagram and a copy of the final building permit, and PG&E then upgrades the meter and issues written permission to operate. The City sends nothing to PG&E for PTO - the one letter it does send PG&E is the unsafe-panel letter under Policy 3.5.11, which is a different transaction. 91% · ordinance + utility DG manual
• Is there a re-inspection fee? $100.18 for the first half hour, plus $100.18 for each additional half hour or portion thereof 90% · fee schedule
• How are corrections issued and cleared? Plan-review corrections: each reviewing department records issues and conditions of approval in the Accela Digital Plan Room and sets its review to 'DENIED'; once all reviews are complete the comments are sent to the applicant or contact. The applicant resubmits revised plans through the Digital Plan Room with a completed Project Revision and/or Transmittal Form and a written response to every comment from every department, with all changes clouded and dated - and a warning that carries teeth: 'ALL SHEETS MUST BE NAMED THE SAME (OR OTHERWISE MATCHED WITH) PREVIOUS VERSIONS, OR THE SUBMITTAL WILL BE DENIED WITHOUT REVIEW AND RETURN TO THE END OF THE REVIEW LINE.' For an expedited solar application, SRCC 18-68.060(F) requires a written correction notice detailing all deficiencies, and (G) requires the resubmittal to be decided within three business days. Field corrections: results are recorded on the inspection card and, for remote inspections, 'Inspection results will be provided in writing via email', with follow-up by email or a morning phone call. 87% · department page