City of Dublin

A city address is usually permitted by the city, not the county — but not always, and some authorities keep building and hand electrical to someone else. Getting this wrong costs the whole submittal, because every requirement below belongs to whoever actually holds jurisdiction. Check the overlays in the same pass: an HOA, a historic district, a windstorm certification or a system-size cap can reshape the design, and all of them are cheaper to find now than after the array is laid out.

• Is this authority the AHJ for residential solar at this address? Yes 95% · department page
• What does this authority permit itself, and what does it delegate? Both 90% · department page
• Is a permit required for a residential rooftop PV system? Yes 97% · adopting ordinance
• Is there a separate electrical permit, or is it combined? Combined 82% · department page
• Is a HOA or architectural approval required first? No city-imposed HOA/architectural-approval requirement found; state law (Civil Code §714, the Solar Rights Act) preempts HOA/CC&R provisions that effectively prohibit or unreasonably restrict rooftop solar, so any HOA review that exists is limited to reasonable, cost/efficiency-neutral aesthetic conditions, not a precondition the city itself imposes. 68% · state statute
• Is there a historic-district review? Conditional Yes: only within the small Dublin Village Historic Overlay Zoning District (DMC Ch. 8.62). There, DMC 8.62.040(B) subjects 'exterior modification of an existing structure...including...roof or ground-mounted mechanical equipment' to Site Development Review. Outside that overlay (the vast majority of Dublin's residential parcels), no historic review applies. 80% · zoning ordinance
• Is a wind or windstorm certification required? No 62% · ordinance
• Is a Specific Use Permit or Council approval ever required? Not for a standard residential rooftop PV system; a Conditional Use Permit or Council/Planning Commission approval could be triggered only in unusual circumstances (e.g., a project needing a height or setback variance, or a Planned Development zoning district with restrictive conditions), none of which is solar-specific in Dublin's zoning code. 55% · ordinance
• Is there a system-size cap on residential generation? No blanket cap on residential system size; the STREAMLINED/expedited permitting pathway (DMC Ch. 7.96 / SolarAPP+) only applies to systems ≤10 kW AC nameplate (or ≤30 kW thermal), matching the state Gov. Code §65850.5 definition. Larger residential systems remain permittable, just outside the expedited track. 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 62% · inference from ordinance + state law
• Is a homeowner permitted to self-install and self-permit? Yes 55% · inference from 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? For SolarAPP+-eligible systems: NREL/SolarAPP+ eligibility checklist plus the design submitted through the SolarAPP+ portal (which generates code-compliant plans). For non-eligible or larger systems, DMC 7.96.050(C)-(D) requires the Building & Safety Division to maintain a standard plan and checklist conforming to the CA Solar Permitting Guidebook (site plan, one-line diagram, equipment spec sheets, structural attachment details). 78% · department page + ordinance
• How many copies, and in what format? Electronic submittal only, through SolarAPP+ or the Citizen Self-Service Portal (CSS/EnerGov); no paper copy count is specified. 75% · ordinance
• Is a site plan required, and what must it show? A site plan is part of the standard SolarAPP+/state-Guidebook submittal package (property lines, existing structures, array location/setbacks, main service equipment location); Dublin's own checklist document could not be located by name, so exact required content is inferred from the SolarAPP+ eligibility framework Dublin has adopted. 60% · inference from ordinance + state guidebook duty
• Is a one-line / three-line diagram required? Yes 72% · inference from ordinance + SolarAPP+ requirements
• Are string and conductor calculations required? Yes 65% · inference from SolarAPP+ program design
• Is a structural PE stamp required, and at what threshold? Not required for systems conforming to the CA Solar Permitting Guidebook standard/prescriptive structural criteria (referenced on Dublin's Green/Electric/Solar page as 'Structural Criteria for Flush-Mounted Solar Arrays'); DMC 7.96.060(A) instead requires the applicant to verify structural adequacy using 'standard engineering evaluation techniques,' which can be self-certified for compliant projects. A PE stamp is expected only where the project falls outside those prescriptive parameters. 65% · ordinance
• Is an electrical PE stamp required, and at what threshold? Not required for standard SolarAPP+-eligible systems; DMC 7.96.060(B) requires the applicant, at their own cost, to verify (not necessarily via PE stamp) that the existing electrical system can carry the new PV load. 55% · ordinance

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? SolarAPP+ (automated review/instant permit) for eligible residential rooftop PV; Citizen Self-Service Portal (CSS), a Tyler Technologies EnerGov instance at dublinca-energovweb.tylerhost.net, for everything else including inspection scheduling 95% · department page
• Can the whole application be completed online? Yes 90% · department page
• What does a residential solar permit cost? $450 flat for a residential rooftop PV system up to 15 kW AC, plus $15 per kW (or fraction) above 15 kW 95% · fee schedule
• How is the fee calculated? Tiered 80% · fee schedule
• Is there a separate plan-check fee? No 68% · 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? Instant/automated for SolarAPP+-eligible systems; approx. 10-15 business days (2-3 weeks) for standard plan-checked building permits generally (not solar-specific) 78% · department page
• How long is an issued permit valid before it expires? 1 year from issuance for permits valued under $1,000,000 (essentially all residential PV); one or more 180-day extensions may be granted by the Building Official for justifiable cause 92% · ordinance
• Which utility handles interconnection here? Pacific Gas & Electric (PG&E) is the interconnecting/distribution utility (owns the wires, handles Rule 21 interconnection and Permission to Operate). Ava Community Energy (CCA, formerly East Bay Community Energy) is Dublin's default electricity GENERATION provider but plays no role in physical interconnection or permitting. 92% · utility's own page
• Where does the utility sit in the sequence? After permit 85% · utility program page

The NEC edition a jurisdiction enforces is often a cycle behind the newest one published, and local amendments sit on top of it. Rapid shutdown, conductor sizing and labelling all change between editions, so the edition in force is the first thing to establish, not the last.

• Which NEC edition is in force? 2023 97% · adopting ordinance
• Which building code edition is in force? 2025 California Building Code (DMC Ch. 7.32) and 2025 California Residential Code (DMC Ch. 7.34) 97% · department page
• Which fire code edition is in force? 2025 California Fire Code, Part 9 (based on the 2024 International Fire Code) 97% · adopting ordinance
• Are there local amendments to any of the above? Yes 90% · ordinance
• What is the installation judged against? The 2025 California Building/Residential Code, 2025 CEC (2023 NEC), and 2025 California Fire Code as locally amended, plus DMC Ch. 7.96's requirement that small residential rooftop PV conform to the current CA Solar Permitting Guidebook standard plans/checklist. 88% · 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? 2025 CFC (based on 2024 IFC) Section 1205.2 family: not fewer than two 36-inch-wide pathways from lowest roof edge to ridge on separate roof planes for Group R-3; ridge setbacks of 18 inches (arrays covering ≤33% of roof area) or 36 inches (>33%), reduced where the building has interior automatic sprinklers. Dublin adopts the CFC without a local amendment to this section. 62% · ordinance (confirms no local amendment) + state code baseline

Which rapid-shutdown rule applies follows directly from the NEC edition in force, and the initiation device has to be at a location the fire service can reach and identify. This is inspected, and it is labelled.

• Is rapid shutdown required, and to which NEC edition? Yes, per NEC 2023 §690.12: array-level rapid shutdown to ≤30V/≤240VA within 30 seconds at the PV system disconnect/controller, and ≤80V outside the array boundary within 10 seconds of initiation. 78% · inference from adopted code edition

The NEC sets a baseline for permanent markings at the service equipment and the disconnecting means. On top of that, an authority may specify its own wording, and the utility may specify more again. Where any of them writes its own text, a generic off-the-shelf label set will not pass — this is the detail most often fixed on a return visit.

• Which placards does this authority require at the service equipment? NEC-required PV/AC disconnect and rapid-shutdown placards at the service equipment, plus PG&E-required placards: an engraved placard for any line-side/supply-side tap connection, and permanent signage on the meter panel indicating an interconnected alternate source of generation (solar/wind/battery). 85% · utility service manual (Greenbook)
• Does the authority specify placard wording of its own? No 70% · ordinance (absence proved by direct read + controls)
• Does it specify letter height, colour or material? No Dublin-specific letter-height/colour/material spec found for PV placards; PG&E's Greenbook Table 7-7 specifies general meter-label material standards (UV-rated identification plates, indelible stencil paint, or manufactured decals for indoor use; tape/handwritten labels are unacceptable for permanent installations). 65% · utility service manual
• Is a site plan / facility map placard required, and what must it show? Not a distinct 'facility map placard' requirement under Dublin's own ordinance; however PG&E's Greenbook requires a map at the meter panel showing the AC disconnect switch location whenever that disconnect is more than 10 feet away or out of line of sight of the meter panel. 60% · utility service manual
• Does the UTILITY specify placards beyond the AHJ's? Yes. PG&E's Greenbook (TD-7001M) requires: (a) an engraved placard for line/supply-side tap connections, (b) permanent signage on the meter panel indicating any interconnected alternate generation source, and (c) signage/a map for the AC disconnect location when it is more than 10 ft from, or out of line of sight of, the meter panel. 90% · utility service manual (Greenbook)
• Where must the labels be placed? At the meter panel/main service equipment, and at the AC disconnect switch itself; if the AC disconnect is more than 10 feet from or not visible from the meter panel, a location map/sign is also required at the meter panel. 85% · utility service manual

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? An AC disconnect is required for all K-base meter panels (any amperage) and for all self-contained/transformer-rated meter panels; for single-phase self-contained/socket-based panels ≤320A it is not required unless a line-side/supply-side tap is used (which always requires a fusible AC disconnect plus an engraved placard). Where installed, the disconnect must be at or within line of sight of the meter panel, or a location map must be posted at the meter panel if it is more than 10 ft away/out of sight. 90% · utility service manual (Greenbook)
• Must equipment be on a specific approved list? Yes 85% · ordinance
• Are batteries permitted, and under what conditions? Yes, batteries/ESS are permitted, governed by the adopted 2025 California Fire Code (energy storage system provisions) with no additional Dublin-specific condition found beyond the standard code and a distinct city permit fee. 82% · fee schedule
• Is there a separate ESS permit or inspection? Yes 85% · fee schedule
• Is a ground mount treated as a structure? Yes 55% · inference from building code administration chapter
• Is there a local rule on service upgrades or busbar sizing? No Dublin-specific local amendment on service-upgrade or busbar sizing was found; the statewide NEC 2023 §705.12(B) 120% rule (and line-side/supply-side tap alternatives) governs as adopted without local modification. 75% · ordinance (absence proved by direct read)
• Is a specific mounting system or attachment spacing required? No Dublin-specific mounting/spacing rule beyond the state 'Structural Criteria for Flush-Mounted Solar Arrays' standard plan set that Dublin's own Green/Electric Vehicle and Solar Information page lists as a resource; that document (part of the CA Solar Permitting Guidebook family) governs attachment spacing for compliant flush-mount installations. 65% · department page (linking to state standard)

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 (CSS/EnerGov online scheduling) or Phone 95% · department page
• How much notice is required? Online: up to 5:00 a.m. the morning of the desired inspection day. Phone: must call by 4:00 p.m. the business day before (effectively 1 business day's notice). 90% · department page
• Are same-day or AM/PM windows offered? AM (8:00 a.m.-12:00 p.m.) and PM (11:00 a.m.-3:00 p.m.) windows are offered; same-day 2-hour windows can be requested by phone between 7:15-8:00 a.m. for already-scheduled inspections. 92% · 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 78% · department page
• If delegated, to whom? Building/electrical: unnamed outside consultant firm(s) contracted by the city (per the Building & Safety page). Fire: Alameda County Fire Department, under a fire-services contract. 70% · department page

A rough-in or mid-roof inspection, where one is required, has to happen before the work it covers is closed up. Missing a stage means opening something back up, and it is the most expensive kind of correction.

• Which inspections are required, and in what order? For SolarAPP+-eligible systems: a single final inspection after installation is the norm (the process moves directly from approved-plan download to inspection scheduling). Non-standard/ground-mount systems may require an additional rough/structural-attachment inspection ahead of the final. 62% · inference from department page
• Is a rough-in or mid-roof inspection required? Not required as a standard step for a flush-mount SolarAPP+ system (only a final inspection is referenced); a mid-roof/rough inspection may be required for non-conforming or ground-mount installations at the inspector's discretion. 55% · inference from department page

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 75% · department page + ordinance
• What must be on site at inspection? The approved plans (downloaded after SolarAPP+ approval), the Dublin permit number (format BLDG-XXXXXX-2026), and a site contact name/phone number, per the information the inspector requests when booking. 72% · department page
• Does the inspector verify labels and listings? Yes 65% · inference from ordinance + standard inspection practice

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 (permit is 'finaled'/closed out in the EnerGov/CSS system upon passing inspection) 62% · inference from department page
• Who notifies the utility for PTO? Installer 88% · utility program page
• Is there a re-inspection fee? $248 per re-inspection (Multi-Family calculated per unit) 90% · fee schedule
• How are corrections issued and cleared? For the streamlined solar pathway, DMC 7.96.070(B)/(E) requires the Building Official to issue a written correction notice detailing all deficiencies for resubmission when an application or inspection reveals non-compliance; standard building-permit corrections follow the general Ch. 7.28 process (notice, re-inspection after correction). 75% · ordinance