HomeMy WebLinkAbout02-03-2015 PH2 Solar Permits and Rainwater CatchmentCity of San Luis Obispo, Council Agenda Report, Meeting Date, Item Number
FROM: Derek Johnson, Community Development Director
Prepared By: Rafael Cornejo, Building & Safety Supervisor
SUBJECT: INTRODUCTION OF AN ORDINANCE OF THE CITY OF SAN LUIS
OBISPO AMENDING TITLE 15 OF THE MUNICIPAL CODE BY
ADDING CHAPTER 15.14 TO PROVIDE AN EXPEDITED,
STREAMLINED PERMITTING PROCESS FOR SMALL
RESIDENTIAL ROOFTOP SOLAR SYSTEMS; AMENDING TITLE 15
OF THE MUNICIPAL CODE BY AMENDING CHAPTER 15.04 TO
EXEMPT CERTAIN RAINWATER CATCHMENT SYSTEMS FROM
PERMITS; AND DETERMINING THAT THE PROJECT IS EXEMPT
FROM CALIFORNIA ENVIRONMENTAL QUALITY ACT
PURSUANT TO SECTION 15061 (b) (3).
RECOMMENDATION
Introduce an Ordinance (2015 Series) amending Title 15 of the Municipal Code to adopt the
California Solar Permitting Guidebook, provide for the exception from permits for rain water
catchment systems, and determine that the project is exempt from the California Environmental
Quality Act pursuant to Section 15061 (b) (3).
BACKGROUND
Solar Permitting
In an effort to provide a more streamlined process for small residential roof mounted solar
photovoltaic installations throughout the State of California, the State prepared and now requires
that local agencies adopt the CA Solar Permitting Guidebook (“Guidebook”). This will enable
jurisdictions to issue the required permits over the counter when in compliance with the
requirements as outlined in the Guidebook. The Guidebook addresses the requirements of the
Solar Permitting Efficiency Act (formerly Assembly Bill 2188) signed into law by Governor
Jerry Brown in September 2014 that requires California’s 540 cities and 58 counties to adopt
streamlined solar permitting processes by Sept. 30, 2015. The intention of the Act is to help drive
down rooftop solar installation costs for residential property owners while increasing
opportunities for solar businesses and to standardize the review process by permitting agencies.
California is the first state to mandate standardized solar permitting processes.
The proposed ordinance is specifically for residential rooftop systems and not commercial
buildings which are much more complex systems and require more in depth review by various
departments and PG&E. Additionally, the proposed ordinance provides an exception for
properties that are on the City’s list of historic resources.
2/3/2015
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Solar and Rain Barrel Permit Streamlining Ordinance Page 2
Rainwater Catchment Systems
The current section in the adopted California Plumbing Code does not allow for a plumbing
permit exception for installation of water tanks that are more than 250 gallons in capacity, thus
requiring a permit for those installations that are more than 250 gallons. Most rain water
catchment systems installed are more than 500 gallons. There are local programs that are
available through government agencies that provide small grant amounts to provide an incentive
for the installation of such systems. In some instances, the current permit process presents a cost
effective barrier to realizing the benefits of the systems.
The proposed ordinance would change the threshold so that systems less than seven feet in
height and 600 gallons would not require a permit. The adoption of this ordinance will allow for
an exception of the permit requirement and thus streamlining this process.
ATTACHMENTS
1. Ordinance # (2015 series) amending Title 15 of the Municipal Code.
AVAILABLE FOR REVIEW IN THE COUNCIL OFFICE
California Solar Permitting Guidebook
AB 2188
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ORDINANCE NO. (2015 Series)
AN ORDINANCE OF THE CITY OF SAN LUIS OBISPO AMENDING TITLE 15 OF
THE MUNICIPAL CODE BY ADDING CHAPTER 15.14 TO PROVIDE AN
EXPEDITED, STREAMLINED PERMITTING PROCESS FOR SMALL RESIDENTIAL
ROOFTOP SOLAR SYSTEMS; AMENDING TITLE 15 OF THE MUNICIPAL CODE
BY AMENDING CHAPTER 15.04 TO EXEMPT CERTAIN RAINWATER
CATCHMENT SYSTEMS FROM PERMITS.
WHEREAS, the City Council of the City of San Luis Obispo recognizes the importance of
“green technology” and by this Ordinance, seeks to (1) implement Assembly Bill 2188 (by
creating an expedited, streamlined permitting process for small residential rooftop solar energy
systems; and (2) promote water conservation by exempting certain rainwater catchment systems
from building permit requirements.
BE IT ORDAINED by the Council of the City of San Luis Obispo as follows:
SECTION 1. Environmental Determination. The project is exempt from environmental review
per CEQA Guidelines under the General Rule (Section 15061(b)(3)). The project involves
updates and revisions to existing regulations. The proposed code amendments are consistent
with California Law, specifically Government Code section 65850.5 and Civil Code section 714.
It can be seen with certainty that the proposed Municipal Code text amendments will have no
significant negative effect on the environment.
SECTION 2. Chapter 15.14, of the City of San Luis Obispo’s Municipal Code, establishing an
expedited, streamlined permitting process for Small Residential Rooftop Solar Systems, is
hereby added to read as follows:
Chapter 15.14 EXPEDITED PERMIT PROCESS FOR SMALL RESIDENTIAL ROOFTOP
SOLAR SYSTEMS
15.14.010 – Purpose and Intent.
The purpose of the chapter is to provide an expedited, streamlined solar permitting
process that complies with the Solar Rights Act and AB 2188 (Chapter 521, Statutes 2014,
CA Govt Code Section 65850.5) in order to achieve timely and cost-effective installations of
small residential rooftop solar energy systems. This chapter encourages the use of solar
systems by removing unreasonable barriers, minimizing costs to property owners and the city
and expanding the ability of property owners to install solar energy systems. This chapter
allows the city to achieve these goals while protecting the public health and safety.
15.14.020 – Definitions
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As used in this chapter:
A. “Solar Energy System” means either of the following:
1. Any solar collector or other solar energy device whose primary purpose is to
provide for the collection, storage, and distribution of solar energy for space
heating, space cooling, electric generation, or water heating.
2. Any structural design feature of a building, whose primary purpose is to
provide for the collection, storage, and distribution of solar energy for
electricity generation, space heating or cooling, or for water heating.
B. “Small residential rooftop solar energy system” means all of the following:
1. A solar energy system that is no larger than 10 kilowatts alternating current
nameplate rating or 30 kilowatts thermal.
2. A solar energy system that conforms to all applicable state fire, structural,
electrical, and other building codes as adopted or amended by the City, and all
state and City health and safety standards.
3. A solar energy system that is installed on a single or two family dwelling.
4. A solar panel or module array that does not exceed the maximum legal
building height as defined by the City.
C. “Electronic submittal” means the utilization of electronic e-mail or submittal via the
internet.
D. “Specific, adverse impact” means a significant, quantifiable, direct, and unavoidable
impact, based on objective, identified, and written public health or safety standards,
policies, or conditions as they existed on the date the application was deemed
complete.
E. “Reasonable restrictions” on a solar energy system are those restrictions that do not
significantly increase the cost of the system or significantly decrease its efficiency or
specified performance, or that allow for an alternative system of comparable cost,
efficiency, and energy conservation benefits.
F. “Restrictions that do not significantly increase the cost of the system or decrease its
efficiency or specified performance” means:
1. For Water Heater Systems or Solar Swimming Pool Heating Systems: an
amount exceeding 10 percent of the cost of the system, but in no case more than
one thousand dollars ($1,000), or decreasing the efficiency of the solar energy
system by an amount exceeding 10 percent, as originally specified and
proposed.
2. For Photovoltaic Systems: an amount not to exceed one thousand dollars
($1,000) over the system cost as originally specified and proposed, or a decrease
in system efficiency of an amount exceeding 10 percent as originally specified
and proposed.
15.14.030-Applicability
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A. This chapter applies to the permitting of all small residential rooftop solar energy
systems in the city.
B. Small residential rooftop solar energy systems legally established or permitted prior
to the effective date of the ordinance codified in this chapter are not subject to the
requirements of this chapter unless physical modifications or alterations are
undertaken that materially change the size, type, or components of a small rooftop
energy system in such a way as to require new permitting. Routine operation and
maintenance or like-kind replacements shall not require a permit.
C. A use permit and/or architectural review may be required for properties on the City’s
list of historic resources as deemed necessary by the Community Development
Director.
15.14.040-Solar Energy System Requirements
A. All solar energy systems shall meet applicable health and safety standards and
requirements imposed by the state and the City.
B. Solar energy systems for heating water in single-family residences and for heating
water in commercial or swimming pool applications shall be certified by an
accredited listing agency as defined by the California Plumbing and Mechanical
Code.
C. Solar energy systems for producing electricity shall meet all applicable safety and
performance standards established by the California Electrical Code, the Institute of
Electrical and Electronics Engineers, and accredited testing laboratories such as
Underwriters Laboratories and, where applicable, rules of the Public Utilities
Commission regarding safety and reliability.
15.14.050-Applications and Documents
A. All documents required for the submission of an expedited solar energy system
application shall be made available on the City website.
B. Electronic submittal of the required permit application and documents by email, or
the Internet shall be made available to all small residential rooftop solar energy
system permit applicants.
C. The city’s Building and Safety Division shall adopt a standard plan and checklist of
all requirements with which small residential rooftop solar energy systems shall
comply to be eligible for expedited review.
D. The small residential rooftop solar system permit process, standard plan(s), and
checklist(s) shall substantially conform to recommendations for expedited permitting,
including the checklist and standard plans contained in the most current version of the
California Solar Permitting Guidebook adopted by the Governor’s Office of Planning
and Research.
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15.14.060-Permit Review and Inspection Requirements
A. The Community Development Director shall implement an administrative,
nondiscretionary review process to expedite approval of small residential rooftop
solar energy systems. The Building and Safety Division shall issue a building
permit, the issuance of which is nondiscretionary, on the same day for over-the-
counter applications or within 1-3 business days for electronic applications upon
receipt of a complete application that meets the requirements of the approved
checklist and standard plan. The Chief Building Official may require an applicant to
apply for an Administrative Use Permit if the official finds, based on substantial
evidence, that the solar energy system could have a specific, adverse impact upon the
public health and safety. Such decisions may be appealed to the city Planning
Commission.
B. Review of the application shall be limited to the Chief Building Official’s review of
whether the application meets local, State, and Federal health and safety
requirements.
C. If an Administrative Use Permit is required, the city may deny such application if it
makes written findings based upon substantive evidence in the record that the
proposed installation would have a specific, adverse impact upon public health or
safety and there is no feasible method to satisfactorily mitigate or avoid, as defined,
the adverse impact. Such findings shall include the basis for the rejection of the
potential feasible alternative for preventing the adverse impact. Such decisions may
be appealed to the city Planning Commission.
D. Any condition imposed on an application shall be designed to mitigate the specific,
adverse impact upon health and safety at the lowest possible cost.
E. “A feasible method to satisfactorily mitigate or avoid the specific, adverse impact”
includes, but is not limited to, any cost-effective method, condition, or mitigation
imposed by the City on another similarly situated application in a prior successful
application for a permit. The City shall use its best efforts to ensure that the selected
method, condition, or mitigation meets the conditions of subparagraphs (A) and (B)
of paragraph (1) of subdivision (d) of Section 714 of the Civil Code defining
restrictions that do not significantly increase the cost of the system or decrease its
efficiency or specified performance.
F. If an application is deemed incomplete, a written correction notice detailing all
deficiencies in the application and any additional information or documentation
required to be eligible for expedited permit issuance shall be sent to the applicant for
resubmission.
G. Only one inspection shall be required and performed by the Building and Safety
Division for small residential rooftop solar energy systems eligible for expedited
review.
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H. The inspection shall be done in a timely manner and should include consolidated
inspections.
I. If a small residential rooftop solar energy system fails inspection, a subsequent
inspection is authorized.
SECTION 3. Section 15.04.020 D is amended to read as follows:
D. Amend Chapter 1, Division II, Section 105.2, Building items 2 and 5 to read as follows:
Work exempt from permit.
Building:
2. Fences not over 6 feet high.
5. A water tank or a group of water tanks intended for storage of irrigation water
only supported directly on grade if the total capacity does not
exceed 250 600 gallons in total on a parcel, and the height does not exceed seven
feet, the ratio of height to width does not exceed 2:1, and it is not visible from the
public right-of-way that abuts the front yard.
SECTION 4: Section 15.04.060 E is added to read as follows:
E. Amend Section 1702.2.1 of the CA Plumbing Code to Read as Follows:
1702.2.1 Permit. It shall be unlawful for a person to construct, install, alter, or cause to
be constructed, installed or altered, a nonpotable rainwater catchment system in a
building or on a premise without first obtaining a permit to do such work from the Chief
Building Official.
Exceptions:
(1) A permit is not required for exterior rainwater catchment systems used for outdoor
non-spray irrigation with a maximum storage capacity of 5000 600 gallons where the
tank is supported directly upon grade, and the ratio of height to diameter or width
does not exceed 2 to 1, and it does not require electrical power or a makeup water
supply connection, the height does not exceed seven feet, and it is not visible from the
public right-of-way that abuts the front yard.
(2) A permit is not required for exterior rainwater catchment systems used for spray
irrigation with a maximum storage capacity of 360 gallons.
SECTION 5. Severability. If any subdivision, paragraph, sentence, clause, or phrase of this
ordinance is, for any reason, held to be invalid or unenforceable by a court of competent
jurisdiction, such invalidity or unenforceability shall not affect the validity or enforcement of the
remaining portions of this ordinance, or any other provisions of the City’s rules and regulations.
It is the City’s express intent that each remaining portion would have been adopted irrespective
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of the fact that any one or more subdivisions, paragraphs, sentences, clauses, or phrases be
declared invalid or unenforceable.
SECTION 6. A summary of this ordinance, together with the names of Council members voting
for and against, shall be published at least five (5) days prior to its final passage, in The Tribune,
a newspaper published and circulated in this City. This ordinance shall go into effect at the
expiration of thirty (30) days after its final passage . A copy of the full text of this ordinance
shall be on file in the Office of the City Clerk on and after the date following introduction and
passage to print and shall be available to any member of the public
INTRODUCED on the 3rd day of February 2015, AND FINALLY ADOPTED by the Council
of the City of San Luis Obispo on the 17th day of February 2015, on the following roll call vote:
AYES:
NOES:
ABSENT:
Mayor Jan Marx
ATTEST:
Anthony J. Mejia
City Clerk
APPROVED AS TO FORM:
J. Christine Dietrick
City Attorney
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Developed by:
Solar Permitting Task Force
Governor’s Office of Planning and Research
Office of Governor Edmund G. Brown Jr.
California
Solar Permitting
Guidebook
Improving Permit Review
and Approval for Small Solar Systems
Fall 2014
Second Edition
California Solar Permitting Guidebook
Improving Permit Review and Approval for Small Solar Systems
Governor’s Office of Planning and Research
Office of Governor Edmund G. Brown Jr.
Project Managers
Claudia Eyzaguirre, Center for Sustainable Energy
Jeffrey Mankey, Governor’s Office of Planning and Research
Lead Contributors
California Building Standards Commission
California Department of Housing and Community Development
California State Fire Marshal
California Solar Energy Industries Association (CALSEIA)
City of Los Angeles
Mar Structural Design
Center for Sustainable Energy
Published fall 2014
Second edition
Partial funding from the U.S. Department of Energy, SunShot Initiative
TABLE OF CONTENTS
PREFACE ....................................................................................................................................4
ACKNOWLEDGMENTS ................................................................................................................5
PURPOSE AND USE OF THIS GUIDE ..........................................................................................6
CURRENT LAWS, REGULATIONS AND CODES .......................................................8
State Code Requirements ..........................................................................................8
Limits on Local Modifications .....................................................................................8
Permit Fees ............................................................................................................10
THE PROJECT APPROVAL PROCESS .....................................................................12
Permit Application and Plan Review .........................................................................12
Site Inspection ........................................................................................................15
Local Utility Approval (Solar PV systems only) ...........................................................15
RECOMMENDATIONS FOR EXPEDITED PERMITTING FOR SMALL PV SYSTEMS ...18
PV Toolkit for Local Governments ............................................................................21
1) Submittal Requirements Bulletin — Solar Photovoltaic Installations
10 kW or Less in One- and Two-Family Dwellings ..........................................22
2) Eligibility Checklist for Expedited Solar Photovoltaic Permitting
for One- and Two-Family Dwellings ..............................................................25
3) Solar PV Standard Plan — Simplified
Central/String Inverter Systems for One- and Two-Family Dwellings ................26
4) Solar PV Standard Plan — Simplified
Microinverter and ACM Systems for One- and Two-Family Dwellings...............39
5) Structural Criteria for Residential
Rooftop Solar Energy Installations ..................................................................45
6) Memorandum of Understanding (MOU) Regarding Solar Photovoltaic
Plan Review and Inspection Services ...............................................................55
7) Inspection Guide for PV Systems in One- and Two-Family Dwellings ................57
RECOMMENDATIONS FOR EXPEDITED SOLAR THERMAL INSTALLATIONS .........65
(Under development)
RESOURCES AND INFORMATION .......................................................................66
Understanding the Code .........................................................................................66
Glossary ................................................................................................................79
Additional Resources .............................................................................................81
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5Part
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3Part
4Part
California Solar Permitting Guidebook4
PREFACE
California is a world leader in renewable energy generation. Solar and wind power, as well as emerging
technologies such as biomass and fuel cells, are transforming California. Renewable energy is helping to power
the state’s economy, reducing our state’s reliance on imported energy sources and decreasing air pollution.
California’s state and local governments have set aggressive goals to expand renewable energy. In 2011,
California adopted a Renewable Portfolio Standard (RPS) requiring that at least one-third of the state’s
electricity come from clean energy sources by 2020. Many local governments also have their own targets for
renewable energy. Additionally, Governor Edmund G. Brown Jr. has set a specific goal of developing 12,000
megawatts of small-scale, localized renewable electrical power (often called “distributed generation”) in
California by 2020.
Small-scale renewable energy benefits California communities. It increases energy reliability for residents and
businesses by generating electricity near where it is consumed. This type of energy can also provide stable
electricity prices for consumers and creates thousands of jobs across California.
In order to expand small-scale renewable energy across California, Governor Brown instructed the Governor’s
Office of Planning and Research (OPR) to help remove barriers to its development. One such barrier is the
patchwork of permitting requirements for small solar installations throughout the state. Solar energy systems
have been installed in California for decades, and their technology, as well as the methods to install and
maintain them, is well established. As a result, permitting for these small and simple solar projects should be as
simple and standardized as possible.
The first California Solar Guidebook
was published in 2012, the result of
a collective effort of stakeholders
from local government, the building
industry, professional associations,
solar companies, utility providers and
state regulatory agencies. Many local
permitting agencies adopted practices
and standard documents outlined in
the Guidebook. These practices made
installing solar less expensive and
increased expansion of this technology
in California.
Despite these improvements, however, costs to permit solar are still higher than necessary. Increased
solar adoption has inundated many jurisdictions with permit applications and inspection requests. Solar
technologies have changed, new laws have been passed and codes have been revised. This second edition of
the Guidebook addresses those changes, improves upon the recommended process for expedited permitting of
solar PV systems, and adds information about solar thermal systems.
California Solar Permitting Guidebook 5
ACKNOWLEDGMENTS
This Guidebook was developed in collaboration with the following individuals and organizations.
Ken Alex, Jeff Mankey Governor’s Office of Planning and Research
Jennifer Alfsen Solar Nexus
George Apple CSD Solar
Mark Baldassari Leo Patnode Enphase Energy
Misha Balmer, Alan Fields, Hilary Pearson Sungevity
Bill Brooks Brooks Engineering
Larry Brugger International Code Council
Steve Burger City of Folsom
California Building Officials (CALBO)
Emilio Camacho, Elli Harland California Energy Commission
Claudia Cappio, Shawn Huff, Kyle Krause, Richard Weinert, Emily Withers Department of Housing and Community Development
Nicholas Chaset California Public Utility Commission
Val Anderson, Daniel Chia, Michael Galvez, Hilary Wall, Rick Hanson SolarCity
Sachu Constantine, Claudia Eyzaguirre, Tamara Gishri Center for Sustainable Energy
Jason Crapo Contra Costa County
Wade Crowfoot Governor’s Office
Andy Davidson Unirac
Bernadette Del Chiaro CALSEIA
Tom Enslow Adams Broadwell
Gary Gerber Sun Light & Power
Sharon Goei City of Walnut Creek
Mark Goodman CLEE
Pete Guisasola Bureau Veritas
Daniel Hamilton ABAG
Alison Healy City of San Francisco
Andrew Henning, Kevin Reinertson, Mike Richwine CalFire
Tonya Hoover State Fire Marshal
Don Hughes Santa Clara County
Peter Jackson City of Bakersfield
Mostafa Kashe Los Angeles County
Janice Kluth City of Chula Vista
Suzanne Korosec, Sherrill Neidich, Le-Quyen Nguyen California Energy Commission
Sheila Lee City of Santa Clara
Brian Leong City of Fresno
Greg Magofna and Sarah Moore City of Berkeley
Jeff Mathias Synergy Solar
Tom McCalmont McCalmont Engineering
Ed Murray Aztec Solar
Jim McGowan, Michael Nearman, Enrique Rodriguez Building Standards Commission
Les Nelson IAPMO
Kimberly Martin, Stephanie Nicholas, Vince Nicoletti San Diego County
Susan Oto Sacramento Municipal Utility District
Matthew Paiss San Jose Fire Department
Rhonda Parkhurst City of Palo Alto
Vance Phillips City of San Ramon
Michael Quiroz 3rd Wave Consulting
Bob Raymer California Building Industry Association
Patrick Redgate AMECO Solar
Rick Renfro City of Elk Grove
Glenn Schainblatt City of Sebastapol
Bill Stewart SolarCraft
John Taecker Underwriters Laboratories
Theresa Townsend Division of the State Architect
Brandon Treloar, Walker Wright Sunrun
Shannan West GO Biz
Scott Wetch Carter, Wetch and Associates
Larry Williams Steel Framing Industry Association
John Wolfe Mar Structural Design
Osama Younan, Behzad Eghtesady City of Los Angeles
Thomas Yurysta Optony
Robert Woods City of Concord
Eddie Bernacchi National Electrical Contractors Association
Brandon Carlson New Day Solar
Adam Gerza Sullivan Solar
California Solar Permitting Guidebook6
PURPOSE AND USE OF THIS GUIDE
This Guidebook is designed to help local governments and their permitting agencies improve permitting of
small solar energy systems. It is also designed to help building owners and solar installers navigate permitting
as efficiently as possible. Practices recommended in this Guidebook apply to permitting agencies of all sizes.
The Guidebook is also written for permit applicants with all levels of expertise.
This Guidebook focuses on the permit review and approval to install a rooftop solar system. It does not
address zoning, land use approvals or environmental review that may be required for larger solar projects.
This Guidebook addresses both solar photovoltaic (PV) and solar hot water heating (solar thermal)
technologies. These technologies have many fundamental similarities, as well as several important differences.
Where requirements are discussed that apply to only one of these technologies, the text will note this.
In the course of the Guidebook, several types of solar installation are discussed, including systems on
residential and commercial building rooftops, in parking lots and on parking structures and mounted on the
ground. It is important to note that each installation type has a certain set of installation requirements. In
addition, rooftop installations have some differing requirements depending whether they are installed on a
commercial or residential building.
The Toolkit section of this Guidebook recommends an expedited permitting process for simple PV systems 10
kW or less and a process for solar thermal systems 30 kWth or less. An expedited permitting process refers to
streamlining the permit process for simple, typical solar installations so that permits can be issued in an “over
THE PROJECT APPROVAL PROCESS: This section describes important
aspects of permit review and project inspection.2Part
RESOURCES AND INFORMATION: This section provides informational
materials that can help local governments clarify current state requirements
for all solar installations.5Part
CURRENT LAWS, REGULATIONS AND CODES: This section explains
current legal requirements for solar installations in California.1Part
The Guidebook is organized into five main sections.
The Guidebook concludes with a glossary of terms and a list of helpful information
sources for local governments and permit applicants.
RECOMMENDATIONS FOR EXPEDITED LOCAL SOLAR PERMITTING:
These sections recommend a streamlined local permitting process for small,
simple solar PV and solar thermal installations, and provide standard forms
that can be used to streamline permitting.
3Part
4Part
California Solar Permitting Guidebook 7
the counter” or similar manner. This Guidebook uses the terms expedited and streamlined synonymously.
These thresholds capture approximately 90% of the solar systems that are currently being installed. Above this
size threshold, a system’s design considerations become more complex.
Assembly Bill 2188 (2014, Muratsuchi) requires jurisdictions to adopt an expedited permitting process that
“substantially conforms” with that laid out in Parts 3 and 4 of this Guidebook. Jurisdictions may modify these
documents as specified and should review these sections of the Guidebook for a more detailed discussion of
this process.
An electronic version of this Guidebook that includes clickable links to Internet resources can be found on
the websites of several California entities: The Governor’s Office of Planning and Research, California
Building Standards Commission, Office of the State Fire Marshal, California Department of Housing and
Community Development and Center for Sustainable Energy.
California Solar Permitting Guidebook8
CURRENT LAWS, REGULATIONS AND CODES
State Code Requirements
California’s state building codes provide uniform requirements for buildings throughout the state. These
requirements are contained in Title 24 of the California Code of Regulations (CCR). The CCR is divided into
28 separate titles based on subject matter or state agency authority. Title 24 is the 24th title within the CCR and
is reserved for state regulations that govern the design and constructions of buildings, associated facilities and
equipment. These regulations are also known as the state’s “building standards.”
Title 24 applies to all building occupancies and related features and equipment throughout the state. It
contains requirements for a building’s structural, mechanical, electrical and plumbing systems, in addition to
measures for energy conservation, sustainable construction, maintenance, fire and life safety and accessibility.
A common misunderstanding is that Title 24 relates only to energy conservation. In fact, it covers a much
wider range of requirements for buildings. Specific areas within Title 24 identify certain requirements for
solar PV installations such as the California Electrical Code, the California Building Code and the California
Residential Code (which applies to residential buildings of one or two units).
State regulations should not be confused with state laws enacted through the legislative process. State
regulations are adopted by state agencies where necessary to implement, clarify and specify requirements of
state law. The California Building Standards Commission and the other state adopting agencies review the
codes and update Title 24 as appropriate. Title 24 is updated every three years.
Several portions of Title 24 govern installation of a solar energy system.
California Building Code, Title 24, Part 2
California Residential Code, Title 24, Part 2.5 (One- and Two-family dwellings)
California Electrical Code, Title 24, Part 3
California Energy Code, Title 24, Part 6
California Fire Code, Title 24, Part 9
The intent of this Guidebook is to provide consistent interpretation of these Title 24 requirements throughout
the state. This Guidebook is not intended to create, explicitly or implicitly, any new requirements.
While current Title 24 requirements establish several legal standards for installation of solar energy
installations, Title 24 may be amended through the state’s code update process to further clarify requirements
for solar PV installations. Updated information regarding new code requirements, as well as the code updating
process, is available on the California Building Standards website.
Limits on Local Modifications
Building Codes
Cities and counties in California are required by state law to enforce Title 24 building standards. However,
cities and counties may adopt local laws (also called “ordinances”) to modify these state building standards
under limited circumstances because of local climatic, geological or topographical conditions. This limited
allowance means that a city or county may have local ordinances that modify or add to the provisions of Title
24 for solar PV systems. The California Building Code (Sections 1.1.8 and 1.1.8.1) outlines the specific
findings that a city or county must make for each amendment, addition or deletion to the state building codes.
1Part
Part 1: Current Laws, Regulations and Codes 9
Cities, counties and local fire departments file these local amendments to the state building code with the
California Building Standards Commission. Findings that are prepared by fire protection districts must
be ratified by the local government and are then filed with the California Department of Housing and
Community Development.
PLANNING AND ZONING REQUIREMENTS
California’s cities and counties have authority to adopt laws that govern local land use. Local governments
typically enforce their own general plans and other comprehensive plans that guide development in their
communities and then adopt local ordinances and zoning regulations to enforce these plans.
Local governments generally can adopt local laws regarding where certain land uses, such as large commercial
energy generation, can be located within their communities. A more detailed conversation regarding land use
and zoning for solar projects is addressed in a 2012 guide produced by the California Planning Directors
Association (CPDA), which is referenced in the Resources section of this Guidebook. This guide recommends
several steps to streamline land use decisions regarding solar energy.
REQUIREMENT TO ADOPT AN EXPEDITED PERMITTING PROCESS FOR SMALL ROOFTOP SOLAR
Assembly Bill 2188 (Muratsuchi, 2014) requires local governments to adopt an administrative ordinance that
creates a streamlined permitting process for small rooftop solar system installations on or before September
30, 2015. It also limits the number of inspections that may be required.
These requirements are applicable to solar energy systems that
1. Are no larger than 10 kilowatts alternating current nameplate rating or 30 kilowatts thermal
2. Conform to all applicable state fire, structural, electrical and other building codes as adopted or
amended by the city, county or city and county and paragraph (3) of subdivision (c) of Section 714
of the Civil Code
3. Are installed on a single-family or duplex family dwelling
4. Do not exceed the maximum legal building height as defined by the authority having jurisdiction
The law also requires that this streamlined process “substantially conform” to the permitting process laid out
in this Guidebook. See Parts 3 and 4 of this Guidebook for an explanation of this process.
Finally, the law sets limits on the cost and efficiency impacts that homeowner associations may have on
proposed solar projects. The full text of this bill can be found here.
RESTRICTIONS TO LOCAL LIMITS ON SOLAR ENERGY
Where solar energy is generated for on-site use, state law clearly limits local governments’ ability to
unreasonably prohibit solar systems. The following state laws place limits on local regulation of solar energy
systems.
California Solar Rights Act
The California Solar Rights Act is a state law, passed in 1979, that elevates the timely and cost-effective
installation of solar energy systems as a matter of statewide importance. The law establishes the right of
homeowners and businesses to access sunlight in order to generate solar energy, limits the ability of local
governments and homeowner associations (HOAs) to prevent the installation of solar systems and prohibits a
public entity from receiving state funding for solar energy programs if it unreasonably restricts the installation
of solar energy systems.
The act’s preamble provides the overarching intent of the act by stating:
California Solar Permitting Guidebook10
It is the intent of the Legislature that local agencies not adopt ordinances that create unreasonable barriers
to the installation of solar energy systems, including, but not limited to, design review for aesthetic purposes,
and not unreasonably restrict the ability of homeowners and agricultural and business concerns to install
solar energy systems. It is the policy of the state to promote and encourage the use of solar energy systems and
to limit obstacles to their use. It is the intent of the Legislature that local agencies comply not only with the
language of this section, but also the legislative intent to encourage the installation of solar energy systems by
removing obstacles to, and minimizing costs of, permitting for such systems.
The Solar Rights Act also requires that local governments use an administrative, nondiscretionary review
process for on-site solar energy systems. As indicated above, no restrictions related to visual or aesthetic
concerns are permitted. Section 65850.5 (c) of the act also prohibits local governments from denying a use
permit for a solar energy system “. . . unless it makes written findings based upon substantial evidence in the
record that the proposed installation would have a specific, adverse impact upon the public health or safety,
and there is no feasible method to satisfactorily mitigate or avoid the specific, adverse impact. The findings
shall include the basis for the rejection of potential feasible alternatives of preventing the adverse impact.”
Specific requirements of the Solar Rights Act have been refined through a series of court cases in recent
decades. For a more detailed understanding of specific legal requirements of this act, please consult a report
completed by the Energy Policy Initiatives Center at the University of San Diego School of Law, which is
detailed in the Resources section at the end of this Guidebook.
Requirements of the Solar Rights Act are contained in the following sections of California law: California Civil
Code, Sections 714 and 714.1; California Civil Code, Sections 801 and 801.5; California Government Code,
Section 65850.5; California Health and Safety Code Section 17959.1; California Government Code, Sections
66473.1 and 66475.3.
California’s Solar Shade Control Act
California’s Solar Shade Control Act, enacted in 1978, is a state law intended to protect solar systems from
being shaded from sunlight by neighboring trees or buildings. A 2008 amendment of this act limits the
application of this law to situations in which a neighbor receives a notice that a solar energy system will be
installed that they might shade if they plant trees or remodel their building.
Requirements of the act are contained in California Public Resources Code, Sections 25980 through 25986.
CEQA Exemption for Certain Solar Installations
Senate Bill 226, passed in 2011, is a state law establishing that certain solar energy systems are exempt from
environmental review under the California Environmental Quality Act (CEQA). To qualify under this
statutory exemption, a solar energy project must be located on the roof of either an existing building or on an
existing parking lot. SB 226 makes clear the legislative intent that rooftop and parking lot solar projects do not
require in-depth environmental review.
This CEQA exemption is contained in Section 21080.35 of the Public Resources Code.
Permit Fees
Current state law requires that fees charged by a local enforcing agency for permit processing and inspection
cannot exceed the reasonable cost of providing the service for which the fee is charged. In other words, fee
revenue must only be used to defray the cost of permit processing and enforcement and cannot be used
for general revenue purposes. These requirements are contained in Government Code Section 65850.55,
Government Code Section 66016 and State Health and Safety Code Section 17951.
Part 1: Current Laws, Regulations and Codes 11
Government Code Section 66015 further sets specific limits on the amount local enforcing agencies can charge
for solar PV permit fees. Fees in excess of these limits must be explicitly justified and are prohibited unless the
municipality determines that it has already adopted a streamlined permit approval process.
Permit Fee Limits for PV
Residential Commercial
15 kW or less $500 50 kW or less $1000
More than 15 kW $500 + $15 per kW
above 15 50 kW – 250 kW $1000 + $7 per kW
above 50 kW
More than 250 kW $2400 + $5 per kW
above 250 kW
While some local governments have yet to comply with these laws, other local governments have reduced or
even waived fees to install solar systems, recognizing the many benefits created by expansion of solar energy in
their communities.
California Solar Permitting Guidebook12
THE PROJECT APPROVAL PROCESS
Securing approval for a solar energy project involves several basic steps. First, a permit application is submitted
to a local permitting agency, known within government as the “enforcing agency” and reviewed by that agency.
Typically, a permit is submitted on behalf of a building owner by the contractor installing the solar energy
system. Once the permit application is approved, the applicant has permission to build the solar installation.
After the solar installation is constructed, it is inspected by the enforcing agency to ensure it complies with
applicable building codes and local ordinances. Each of these steps is described in more detail below.
For solar PV installations, during the local agency project approval process the permit applicant should also
contact the local utility provider to request permission to connect the solar installation to the local distribution
grid. The solar PV system cannot be “turned on” until approval is granted by both the local agency and the
local utility.
Well-informed solar installers and knowledgeable, well-trained local agency staff are critical to achieve an
efficient permit approval process. Please consult the Resources section of this Guidebook for information on
training available to both solar contractors and agency staff. Effective training is one of the most important
steps that local governments and the solar industry can take to ensure efficient permitting.
Permit Application and Plan Review
This section explains the permit review process for solar energy installations and common issues that must be
addressed to minimized unexpected delays in the permit review process.
Enforcing Agency Review
The first step to build a solar installation requires applying for a permit to construct the installation from
the local enforcing agency, which is most often the local building department. Each local enforcing agency
is organized slightly differently, but all have an established process for receiving, reviewing and approving
permits.
Submit permit
application
and materials
Permit review
and approval
Submit request to “interconnect”
the solar installation to the
local electricity grid
Construction
of solar PV
system
Site inspection and
interconnection approval
Site inspection
and final
approval
STEPS FOR PERMIT REVIEW AND APPROVAL
Local Enforcing Agency Review
Local Utility Approval
2Part
Part 2: The Project Approval Process 13
The local agency enforces all Title 24 requirements from the state as well as any local requirements on solar
energy installations. In many cases, the local agency must interpret how state requirements apply to certain
buildings. The enforcing agency must verify that the installation complies with structural requirements and for
solar PV installations must verify that it meets electrical requirements and applicable fire safety ratings. Each
of these areas is discussed in detail.
Structural Requirements
Installation of a solar energy system on the roof of a structure adds weight to the structure, commonly referred
to as “dead load.” This additional weight must be accounted for to ensure that the building can safely bear the
weight of the solar installation. In new construction, this additional load is usually addressed easily and at very
little cost. Where a solar system is added to existing buildings, the cost and complexity of adding weight to the
roof vary depending on the structure of the building and roof.
Solar panels also may impose loads generated by seismic forces and, in some areas, by snow accumulation.
Solar panels must also resist wind forces.
The California Building Code and California Residential Code contain specific tables that determine the
required size and spacing of structural support for a roof according to assumed design loads based on roof
covering, roof slope and snow loads. These specific tables do not address structural support that is required for
additional equipment on rooftops such as PV systems.
Roof structures are also designed to carry temporary construction loads, termed “roof live loads,” in addition
to the self-weight of the structure. Solar arrays, if installed close to the roof surface, displace roof live loads
such as workers and bundles of shingles. This displacement of roof live load creates reserve load-bearing
capacity that can be used to justify additional dead and wind loads from solar arrays. This approach is the
basis of the Structural Toolkit on page 31 that enables “over-the-counter” permitting for prequalified systems
without requiring project-specific structural calculations.
Building codes do provide design criteria that an engineer or architect can use to calculate the required
structural support required for additional loads on rooftops, such as solar energy systems. The Solar
Guidebook’s Structural Toolkit suggests criteria for when a licensed engineer or architecture may need to
be consulted when adding solar arrays to a roof structure and when a prequalified system does not require
project-specific structural calculations. By reviewing a jurisdiction’s expedited procedures, permit applicants
can learn when the local enforcing agency specifically requires the services of a licensed engineer or architect
to verify proposed plans for a solar energy system, and when the jurisdiction has an alternate method that
waives such requirements.
Electrical Requirements (Solar PV systems only)
Individual components of solar PV systems must comply with the California Electrical Code (CEC). This
requirement applies to several system components, including but not limited to the installation’s panels,
modules, wire, inverters, connectors and disconnects. The CEC requires these components in the solar
PV system to be “identified and listed for the application.” It is important to ensure that the solar system’s
components are listed within a product standard that covers the proposed use.
Currently, no complete system listings exist for solar installations, but rather system listings exist for a solar
PV installation’s individual components. Components that are identified and listed for solar PV installation
application must be installed in accordance with both the California Electrical Code and the manufacturers’
installation instructions. Solar PV systems that use components listed for the application and are properly
designed and installed constitute a code-compliant system from an electrical standpoint.
California Solar Permitting Guidebook14
In some circumstances, a professional electrical engineer may be required to design the electrical portion of
the proposed solar PV system. The enforcing agency determines if this is necessary based on the complexity
of the system. In many cases, an electrical engineer is not required, as licensed contractors are capable of
completing the necessary sizing calculations and can specify the components needed to make smaller systems
work safely and properly.
The California Electrical Code requires that portions of electrical systems, including solar PV systems, should
only be accessed by qualified persons. This rule is intended to ensure that only people who have training or
understand relevant hazards are allowed in certain areas of an electrical installation.
Fire Classification, Safety and Roof Access and Pathway Requirements
(Solar PV systems only)
Buildings in California may be required to have a fire resistant roof covering, depending on the type of
construction, occupancy or geographical location of the building. The California Building and Residential
Codes recognize three fire resistant roof ratings: Class A, B and C. These ratings are established through
specific testing methods based on the ability of the roof covering to withstand fire that comes from a source on
top of the roof structure. Roof materials with Class A fire resistance rating can withstand a high exposure to
fire without allowing penetration or ignition of the structure, while Class B and C materials have lesser ability
to withstand fire.
California statutorily requires all roof materials installed on buildings throughout state to have a minimum
Class C rating. Beginning in 2015, solar panels must have a fire resistant rating that conforms to the fire rating
of the roof beneath.1
The installation of solar PV systems must also allow for fire department smoke ventilation operations. The
California Building, Residential and Fire Codes outline the requirements for a roof access point and clear
access pathways along the roof (for more detail on these requirements see the Code Bulletin in the Reference
Toolkit). The installation of solar PV systems may be subject to additional provisions adopted by the local
enforcing agency.
Fire Service Approval (Solar PV systems only)
Permits for solar PV installations are reviewed to ensure compliance with fire safety requirements. In many
communities, the enforcing agency coordinates directly with the fire department to ensure fire safety of PV
projects and the permit applicant does not have any direct contact with the fire department.
In some areas, the local fire authority is a fire district or special service district organized to provide fire
services. Unlike a fire department, which is typically part of a city or county government, a fire district
operates independently under the direction of a locally elected board. Many jurisdictions have established
a memorandum of understanding between the local fire authority and the building official that allows the
building official to determine and approve fire safety requirements.
In circumstances where the fire authority is separate from city or county government and no MOU established,
applicants should contact the local fire authority early in the planning stages of a PV installation to determine
if there are any unique requirements or approval process within the specific jurisdiction.
In 2008, the California Office of the State Fire Marshal released a final draft guideline related to solar PV roof
installations. This document was developed through collaboration with local fire departments and the solar
industry with safety as the principal objective. The guideline’s intent was to provide the solar industry with
information to aid in designing, building and installing PV systems to meet this objective.
1 Other requirements for higher classification may apply. Also see California State Fire Marshal Bulletin 14-002 and addendum.
Part 2: The Project Approval Process 15
Portions of the 2008 State Fire Marshal guideline were adopted into the 2012 International Fire Code and are
included in the 2013 California Building, Residential and Fire Codes. Permit applicants should contact the
local fire authority to determine if specific fire safety requirements beyond current state regulations have been
adopted in the local jurisdiction.
Planning and Zoning
As noted earlier in this guide, California cities and counties have authority to adopt laws that govern local
land use, but are limited from restricting solar energy systems where energy is being generated for use on-site.
Local governments have more latitude to determine where large, commercial energy generation can be located
within their communities. For commercial solar energy projects, developers should determine what if any
local plans, laws or regulations govern where the project can be located.
Site Inspection
After a solar energy system is installed, an inspector from the local enforcing agency physically inspects the
installation. This field inspection is the last step before final project approval is granted by the local enforcing
agency (note that a PV system cannot begin operating until it has received approval from both the local
enforcing agency and the local utility). The field inspection ensures the solar energy system has been installed
properly and according to the approved plans. Some local governments conduct “rough” or preinspections to
ensure, for example, that roof penetrations are compliant with code or other requirements. Others may inspect
the structural integrity of a building prior to installation.
Inspections focus on verifying that an installation is compliant with applicable building code, electrical code
and fire safety requirements. To ensure building code compliance, an inspection will verify proper material
selection, soundness of structural attachment to the roof or ground and that all components are securely
fastened. Inspection of a solar PV installation’s electrical system often focuses on wiring methods, circuit
protection, grounding and safety signage. To ensure fire safety of a solar PV installation, the inspection verifies
labeling of equipment to limit firefighter exposure to electrical voltage, space for firefighters to access the
building or structure and limitations in roof installations due to firefighting suppression techniques.
Currently, inspection standards for solar energy systems can differ among jurisdictions due to differing
interpretations of code standards and inconsistent expertise among field inspectors. Permit applicants
should ask the local enforcing agency to provide a clear explanation of what the on-site inspection will entail,
including what elements of the system the inspector will examine. This Guidebook provides a set of standard
inspection criteria, which will eliminate much of this variation if adopted by jurisdictions.
Local enforcing agencies also schedule and execute site inspections differently. Many jurisdictions are able
to complete a site inspection within one or two days of notice that construction of the solar installation is
completed, while others may take longer. Similarly, some enforcing agencies are able to predict a narrow
window of time within which an inspector will visit a property, which saves the permit applicant’s time and
money, while other agencies are less precise. Enforcing agencies should work to minimize the delay between
the permit approval and site inspection and to minimize the inspection window. Finally, enforcing agencies
should strive to eliminate “rough” or preinspections and, instead, ensure compliance with all applicable rules
and requirements during the final inspection.
Local Utility Approval (Solar PV systems only)
All solar PV installations need the local utility’s approval to link into the electricity grid, a process commonly
referred to as “interconnection.” This interconnection approval must be granted before a solar PV installation
California Solar Permitting Guidebook16
is allowed to operate and is completely separate from local government approval for the solar installation.
Interconnection approval ensures that a solar installation will safely connect and operate on the electricity grid.
Understanding the utility’s requirements and process is very important. Permit applicants should contact the
local electric utility at the beginning of the project planning stage. Utilities provide information about required
interconnection agreements and can also provide information about available financial rebates or incentives.
A permit applicant may also apply to the local utility for incentives available for new solar systems under
the California Solar Initiative. To qualify for rebates or other incentives, property owners may be required to
complete an energy audit before installing a PV system.
California’s local utilities differ regarding when they require or allow filing an interconnection application
during the local enforcing agency review process. Electric utilities may require or request that a contractor
submit their application to the utility for review before a building permit is issued by the local city or county.
Also, utilities may require one or more on-site inspections of the project before approving the interconnection
agreement. This inspection process is completely different from an inspection performed by the local
permitting agency.
The Public Utilities Code requires that all electric utilities respond within 30 working days after receiving a
completed application for interconnection. To help ensure an application is considered complete when first
submitted, permit applicants should contact their electric utility to learn the specific information and forms
that must be included in the application.
Each utility provides information on its process for interconnection approval for solar PV installations on its website.
The Resources section of this Guidebook provides weblinks to this information for the state’s largest utilities.
QUICK TIPS FOR CONTRACTORS & PROPERTY OWNERS
WHEN APPLYING FOR A PERMIT
Permit applicants can save time and money by following these tips.
• Take time to review permit requirements of the local jurisdiction
Permitting rules and processes differ among different cities and counties. Understanding all local
requirements will allow permit applicants to submit a complete and accurate permit application
packet the first time.
• Contact the local electric utility early in the permitting process (solar PV
installations)
Local electric utilities have a completely separate approval process from the local jurisdiction’s
permitting process. Some electric utilities may require that the solar project be reviewed before
the local jurisdiction issues a building permit. Pursuing utility approval early in the permit process
enables the solar PV system to become operational as soon as possible.
• Make sure that the solar installation that is built matches the submitted plans
The on-site inspector will verify that the installation aligns with proposed plans and any changes
may require corrections and additional inspections.
Part 2: The Project Approval Process 17
QUICK TIPS FOR LOCAL PERMITTING AGENCIES
Local agencies can save valuable staff time and resources by following these tips.
• Provide clear written instructions on the permitting process
Making this information available on the Internet and at the department’s counter are low-cost
ways to reduce errors by permit applicants.
• Take advantage of information technology
Online or electronic application submittal and permit issuance, including use of e-signatures,
can minimize or eliminate backlogs at the counter and, thus, free up staff time to focus on more
complex permit applications.
• Use standardized forms
Using standard forms that permit applicants simply fill out simplifies review for staff and reduces
the possibility of omitted information.
• Consider hosting contractor training events
Partnering with the solar contractor community to train contractors on proper permit submittals
represents a small investment of time that may avoid hours of staff work processing flawed
permitting applications.
• Standardize requirements across jurisdictions
Using common permit materials, such as checklists and standard plans, across city and county
lines reduces permit submittal errors among contractors working throughout a region.
California Solar Permitting Guidebook18
RECOMMENDATIONS FOR EXPEDITED
PERMITTING FOR SMALL PV SYSTEMS
A streamlined, expedited permit process for small solar PV systems that simplifies and consolidates the
structural, electrical and fire review of the PV system, can eliminate the need for detailed engineering studies
and avoids unnecessary delays. Many local governments in California have already taken steps to streamline
solar permitting realizing resource savings and increased throughput. These efforts have helped to inform the
following recommendations.
A streamlined permit process for solar PV projects 10 kW or less includes, but is not limited to, the
following elements.
• Use of a simple eligibility checklist to determine whether projects qualify for
expedited permitting and requisite written materials.
• Use of a standard plan to describe the proposed solar PV project in the permit
application. A standard plan reduces applicant errors and can simplify review.
• Permit application materials are made available through the Internet.
• Application submittals, fee payment, signatures and permit issuance are
completed electronically, where capability exists.
• A streamlined process for structural review.
• For eligible projects, plan review and permit issuance are completed “over
the counter” for walk-in applications or electronic submittals, or automatically
through online software. If over-the-counter approval is not offered, a maximum
timeframe of 1-3 days in which to review the permit application is provided.
A streamlined inspection process for solar PV systems should include the following.
• A single, final inspection coordinated among the various agencies or for
inspections by multiple agencies to occur at the same time. Typically this involves
coordination between the building department and the local fire authority.
• Use of a concise inspection list that provides permit applicants a clear
understanding of what elements of the solar installation will be inspected
before final approval of the installation.
• Enable inspection requests to be submitted online or electronically.
• Provide for on-site inspection during the next business day after notification
that the solar system has been installed. If next business day not possible,
schedule inspection within five days.
• Provide a scheduling time window for on-site inspection of no more than two
hours, and utilize phone and/or email communication to provide information
on anticipated inspection time.
• The most streamlined permit process also ensures close coordination between
the building department and the local utility to coordinate on-site inspections.
3Part
Part 3: Recommendations for Expedited Permitting for Small PV Systems 19
The model streamlined permit process recommended in this section is intended to apply to PV systems with
a maximum power output of 10 kW or less that meet certain criteria. As PV systems increase in size and
complexity, the ability to handle these projects via a standard framework diminishes. However, it should be
noted that larger PV systems or installations with complicating factors can still be approved in a timely manner
through a clear and efficient permit review process.
It is not the intent of an expedited process to circumvent the engineering process. Rather, the intent of a
streamlined process is to recognize the similarities among these smaller systems and establish guidelines to
determine when a PV project is within the boundaries of typical, well-engineered systems.
Efficient permitting requires cooperation among local permitting staff and solar contractors. Many local
enforcing agencies have provided informational training for agency staff and solar contractors to explain local
requirements and vice versa. This training has resulted in better educated staff and contractors, reducing
permit application errors and saving time and resources for the local permitting agency.
PV Toolkit for Local Governments
The seven template documents provided in this section form an optional toolkit that local governments can
utilize to reduce their costs of permit review, approval and inspection, and to ensure a predictable and efficient
process for permit applicants.
Assembly Bill 2188 (2014, Muratsuchi) requires local governments to adopt an expedited permitting process
that “substantially conforms” with the process outlined in this Guidebook. According to the bill’s author:
“The term ‘substantially conform’ is intended to allow local governments enough flexibility to address
potential changes that they believe are necessary while still meeting the goal of streamlining and
standardizing solar permitting. Further, AB 2188 states that local governments may modify the Guidebook, if
necessary, due to ‘unique climatic, geological, seismological or topographical conditions.’ These modifiers are
intended to provide additional flexibility for local governments and are not intended to limit how the cities
and counties ‘substantially conform’ to the Guidebook.”
The author further notes that this flexibility is also intended to allow jurisdictions to make any changes
necessary to reflect the operational needs of local fire departments or districts.
The templates in this toolkit can be adopted in many jurisdictions with only minor administrative adjustments.
However, building officials should review these documents and the assumptions on which they are based, and
make further modifications as necessary to meet the needs of their jurisdiction. Jurisdictions are not required
to notify the Building Standards Commission of modifications to these documents when adopted.
Templates for streamlining permitting of small systems (10 kW or less) on one- and
two-family homes
• Submittal Requirements Bulletin — Outlines the necessary steps to secure permits and details
what materials must be submitted in the permit application and key points of the on-site inspection.
• Eligibility Checklist — Defines the size, electrical, structural and fire safety requirements for solar
installations to qualify for streamlined permitting.
• Standard Electrical Plans — Enable applicants to “fill in the blanks” to explain the electrical
configuration of a solar PV system. This toolkit offers two simplified standard plans that can be
used for small solar PV installations: one for systems using a central/string inverter and another for
systems utilizing microinverters. Comprehensive standard plans for central/string inverter and for
California Solar Permitting Guidebook20
microinverters are available online, provide instructions for the simplified standard plans and can
be used for PV installations that do not fit into the simplified plans.
Materials to further improve permitting of solar PV systems of all sizes
• Example MOU (memorandum of understanding) — Provides a template agreement between two
local agencies to coordinate permit review and approval. It can be used, for example, to streamline
review between a local building department and a local fire service.
• Structural Criteria — Ensures structural code compliance for flush-mounted solar arrays. It
enables applicants to submit a simple list and supporting documents after conducting a site audit
to determine structural conditions. A technical appendix describing the technical analysis behind
these criteria is listed in the Additional Resources section.
• Technical Information Bulletin for Solar PV Systems (on all types of buildings) — Provides
consistent and comprehensive information regarding current state requirements for solar
PV systems on all buildings, including both residential and commercial buildings, in a local
jurisdiction. It could be issued as a department advisory or as an informational handout and can
be used by solar installers as a reference document. Enforcing agencies can modify the information
bulletin based on local needs or policies.
• Inspection Guide — Provides a code reference and field inspection sheet for solar PV systems
inspections. This guide is meant to improve consistency and uniformity in inspections and to
provide permit applicants with a clear understanding of the process.
Part 3: PV Toolkit for Local Governments 21
PV Toolkit for Local Governments
Template permitting documents that local governments can edit are available at
energycenter.org/permittingtoolkit
California Solar Permitting Guidebook22
TOOLKIT DOCUMENT #1
Submittal Requirements Bulletin —
Solar Photovoltaic Installations 10 kW or Less
in One- and Two-Family Dwellings
Yo ur City
logo here
This information bulletin is published to guide applicants through a streamlined permitting process for solar
photovoltaic (PV) projects 10 kW in size or smaller. This bulletin provides information about submittal
requirements for plan review, required fees and inspections.
Note: Language in ALL CAPS below indicates where local jurisdictions need to provide information specific to the
jurisdiction. Language in italics indicates explanatory notes from the authors of this Guidebook.
1. Approval Requirements
The following permits are required to install a solar PV system with a maximum power output of 10 kW
or less:
a) [LIST TYPE OF PERMIT(S) REQUIRED BY THE LOCAL JURISDICTION, i.e., ELECTRICAL OR
BUILDING PERMIT].
Planning review [IS/IS NOT] required for solar PV installations of this size.
Fire Department approval [IS/IS NOT] required for solar PV installations of this size.
2. Submittal Requirements
a) Completed permit application form. This permit application form can be downloaded at [WEBSITE
ADDRESS].
b) Demonstrate compliance with the eligibility checklist for expedited permitting. These criteria can be
downloaded at [WEBSITE ADDRESS].
This Guidebook recommends use of a simple checklist to clearly identify eligibility criteria for expedited
permitting, where established.
c) A completed Standard Electrical Plan. The standard plan may be used for proposed solar installations
10 kW in size or smaller and can be downloaded at [WEBSITE ADDRESS].
This Guidebook recommends use of a standard plan that allows permit applicants to simply fill in information
regarding a solar system’s electrical configuration. Template standard plans are provided in this Guidebook
(Toolkit Documents 3 and 4).
If standard electrical plans are not provided for use, an electrical plan should be submitted that includes the
following.
• Locations of main service or utility disconnect
• Total number of modules, number of modules per string and the total number of strings
• Make and model of inverter(s) and/or combiner box if used
• One-line diagram of system
• Specify grounding/bonding, conductor type and size, conduit type and size and number of conductors in
each section of conduit
• If batteries are to be installed, include them in the diagram and show their locations and venting
Part 3: PV Toolkit for Local Governments 23
• Equipment cut sheets including inverters, modules, AC and DC disconnects, combiners and wind
generators
• Labeling of equipment as required by CEC, Sections 690 and 705
• Site diagram showing the arrangement of panels on the roof or ground, north arrow, lot dimensions and
the distance from property lines to adjacent buildings/structures (existing and proposed)
d) A roof plan showing roof layout, PV panels and the following fire safety items: approximate location
of roof access point, location of code-compliant access pathways, PV system fire classification
and the locations of all required labels and markings. Examples of clear path access pathways are
available in the State Fire Marshal Solar PV Installation Guide. http://osfm.fire.ca.gov/pdf/reports/
solarphotovoltaicguideline.pdf.
e) Completed expedited Structural Criteria along with required documentation. Structural Criteria can
be downloaded at [WEBSITE ADDRESS].
For non-qualifying systems, provide structural drawings and calculations stamped and signed by a
California-licensed Civil or Structural Engineer, along with the following information.
• The type of roof covering and the number of roof coverings installed
• Type of roof framing, size of members and spacing
• Weight of panels, support locations and method of attachment
• Framing plan and details for any work necessary to strengthen the existing roof structure
• Site-specific structural calculations
• Where an approved racking system is used, provide documentation showing manufacturer of the rack
system, maximum allowable weight the system can support, attachment method to the roof or ground
and product evaluation information or structural design for the rack system
This Guidebook recommends that local jurisdictions adopt a prescriptive approach to establishing minimal
structural requirements that avoids the need for structural calculations. A simple list of criteria is provided
in this Guidebook (Toolkit Document 5). A full explanation of the methods and calculations used to produce
these criteria can be found in the Structural Technical Appendix for Residential Rooftop Solar Installations,
which is available at http://www.opr.ca.gov/docs/Solar_Structural_Technical_Appendix.pdf.
3. Plan Review
Permit applications can be submitted to [DEPARTMENT NAME] in person at [ADDRESS] and [IF
APPLICABLE] electronically through the following website: [WEBSITE/EMAIL/FAX].
Permit applications utilizing standard plan may be approved “over the counter” at [ADDRESS]. Permit
applications may also be submitted electronically for “over the counter” approval [IF APPLICABLE] at the
following website: [WEBSITE/EMAIL/FAX].
Permits not approved “over the counter” should be reviewed in [ONE TO THREE] days.
4. Fees
[PROVIDE CLEAR FEE SCHEDULE]
5. Inspections
Once all permits to construct the solar installation have been issued and the system has been installed, it must
be inspected before final approval is granted for the solar system. On-site inspections can be scheduled by
contacting [DEPARTMENT] by telephone at [PHONE NUMBER] or electronically at [WEBSITE OR EMAIL
ADDRESS]. Inspection requests received within business hours are typically scheduled for the next business
day. If next business day is not available, inspection should happen within a five-day window.
California Solar Permitting Guidebook24
Permit holders must be prepared to show conformance with all technical requirements in the field at the
time of inspection. The inspector will verify that the installation is in conformance with applicable code
requirements and with the approved plans.
The inspection checklist provides an overview of common points of inspection that the applicant should be
prepared to show compliance. If not available, common checks include the following.
• Number of PV modules and model number match plans and specification sheets number match plans
and specification sheets.
• Array conductors and components are installed in a neat and workman-like manner.
• PV array is properly grounded.
• Electrical boxes are accessible and connections are suitable for environment.
• Array is fastened and sealed according to attachment detail.
• Conductors ratings and sizes match plans.
• Appropriate signs are property constructed, installed and displayed, including the following.
–Sign identifying PV power source system attributes at DC disconnect
–Sign identifying AC point of connection
–Sign identifying switch for alternative power system
• Equipment ratings are consistent with application and installed signs on the installation, including the
following.
–Inverter has a rating as high as max voltage on PV power source sign.
–DC-side overcurrent circuit protection devices (OCPDs) are DC rated at least as high as max
voltage on sign.
–Switches and OCPDs are installed according to the manufacturer’s specifications (i.e., many
600VDC switches require passing through the switch poles twice in a specific way).
–Inverter is rated for the site AC voltage supplied and shown on the AC point of connection sign.
–OCPD connected to the AC output of the inverter is rated at least 125% of maximum current on
sign and is no larger than the maximum OCPD on the inverter listing label.
–Sum of the main OCPD and the inverter OCPD is rated for not more than 120% of the bus bar rating.
6. Departmental Contact Information
For additional information regarding this permit process, please consult our departmental website at
[WEBSITE] or contact [DIVISION NAME] at [PHONE NUMBER].
Part 3: PV Toolkit for Local Governments 25
TOOLKIT DOCUMENT #2
Eligibility Checklist for Expedited
Solar Photovoltaic Permitting for
One- and Two-Family Dwellings
Your City
logo here
GENERAL REQUIREMENTS
A. System size is 10 kW AC CEC rating or less Y N
B. The solar array is roof-mounted on one- or two-family dwelling or accessory structure Y N
C. The solar panel/module arrays will not exceed the maximum legal building height Y N
D. Solar system is utility interactive and without battery storage Y N
E. Permit application is completed and attached Y N
ELECTRICAL REQUIREMENTS
A. No more than four photovoltaic module strings are connected to each Maximum Power
Point Tracking (MPPT) input where source circuit fusing is included in the inverter Y N
1) No more than two strings per MPPT input where source circuit fusing is not included Y N
2) Fuses (if needed) are rated to the series fuse rating of the PV module Y N
3) No more than one noninverter-integrated DC combiner is utilized per inverter Y N
B. For central inverter systems: No more than two inverters are utilized Y N
C. The PV system is interconnected to a single-phase AC service panel of nominal
120/220 Vac with a bus bar rating of 225 A or less Y N
D. The PV system is connected to the load side of the utility distribution equipment Y N
E. A Solar PV Standard Plan and supporting documentation is completed and attached Y N
STRUCTURAL REQUIREMENTS
A. A completed Structural Criteria and supporting documentation is attached (if required) Y N
FIRE SAFETY REQUIREMENTS
A. Clear access pathways provided Y N
B. Fire classification solar system is provided Y N
C. All required markings and labels are provided Y N
D. A diagram of the roof layout of all panels, modules, clear access pathways and
approximate locations of electrical disconnecting means and roof access points
is completed and attached Y N
Notes:
1. These criteria are intended for expedited solar permitting process.
2. If any items are checked NO, revise design to fit within Eligibility Checklist, otherwise permit application
may go through standard process.
California Solar Permitting Guidebook26
TOOLKIT DOCUMENT #3
Solar PV Standard Plan — Simplified
Central/String Inverter Systems for
One- and Two-Family Dwellings
Your City
logo here
SCOPE: Use this plan ONLY for utility-interactive central/string inverter systems not exceeding a system AC inverter output rating of
10kW on the roof of a one- or two-family dwelling or accessory structure. The photovoltaic system must interconnect to the load side of
a single-phase AC service panel of nominal 120/240Vac with a bus bar rating of 225A or less. This plan is not intended for bipolar
systems, hybrid systems or systems that utilize storage batteries, charge controllers, trackers, more than two inverters or more than one
DC combiner (noninverter-integrated) per inverter. Systems must be in compliance with current California Building Standards Codes and
local amendments of the authority having jurisdiction (AHJ). Other Articles of the California Electrical Code (CEC) shall apply as specified
in 690.3.
MANUFACTURER’S SPECIFICATION SHEETS MUST BE PROVIDED for proposed inverter, modules, combiner/junction boxes and racking
systems. Installation instructions for bonding and grounding equipment shall be provided, and local AHJs may require additional
details. Listed and labeled equipment shall be installed and used in accordance with any instructions included in the listing or labeling
(CEC 110.3). Equipment intended for use with PV system shall be identified and listed for the application (CEC 690.4[D]).
Job Address: ______________________________________________ Permit #: ________________________
Contractor/ Engineer Name: ________________________________ License # and Class: _______________
Signature: _______________________________ Date: ___________ Phone Number: __________________
Total # of Inverters installed: __________ (If more than one inverter, complete and attach the “Supplemental
Calculation Sheets” and the “Load Center Calculations” if a new load center is to be used.)
Inverter 1 AC Output Power Rating: _______________________ Watts
Inverter 2 AC Output Power Rating (if applicable): ____________ Watts
Combined Inverter Output Power Rating: ___________________ ≤ 10,000 Watts
Location Ambient Temperatures (Check box next to which lowest expected temperature is used):
1) Lowest expected ambient temperature for the location (TL ) = Between -1 to -5 °C
Lowest expected ambient temperature for the location (TL ) = Between -6 to -10 °C
Average ambient high temperature (TH) = 47 °C
Note: For a lower TL or a higher TH, use the Comprehensive Standard Plan
DC Information:
Module Manufacturer: __________________________ Model: ______________________________
2) Module Voc (from module nameplate): ______ Volts 3) Module Isc (from module nameplate): ______ Amps
4) Module DC output power under standard test conditions (STC) = ________ Watts (STC)
Part 3: PV Toolkit for Local Governments 27
5) DC Module Layout
Identify each source circuit
(string) for inverter 1 shown
on the roof plan with a Tag
(e.g. A,B,C,…)
Number of modules per
source circuit for inverter 1
Identify, by tag, which source circuits on the roof are to be
paralleled (if none, put N/A)
Combiner 1:
Combiner 2:
Total number of source circuits for inverter 1:
6) Are DC/DC Converters used? Yes No If No, skip to Step 7. If Yes enter info below.
DC/DC Converter Model #: __________________
Max DC Output Current: ____________________ Amps
Max # of DC/DC Converters in an Input Circuit: ___________
DC/DC Converter Max DC Input Voltage: ______ Volts
Max DC Output Current: ___________________ Volts
DC/DC Converter Max DC Input Power: _______ Watts
7) Maximum System DC Voltage — Use A1 or A2 for systems without DC/DC converters, and B1 or B2 with DC/DC Converters.
A1. Module VOC (STEP 2) = ____________ x # in series (STEP 5) ___________ x 1.12 (If -1 ≤ TL ≤ -5°C, STEP 1) = ____________ V
A2. Module VOC (STEP 2) = ____________ x # in series (STEP 5) ___________ x 1.14 (If -6 ≤ TL ≤ -10°C, STEP 1) = ___________ V
Table 1. Maximum Number of PV Modules in Series Based on Module Rated VOC for 600 Vdc Rated Equipment (CEC 690.7)
Max. Rated Module VOC (*1.12)
(Volts)29.76 31.51 33.48 35.71 38.27 41.21 44.64 48.70 53.57 59.52 66.96 76.53 89.29
Max. Rated Module VOC (*1.14)
(Volts)29.24 30.96 32.89 35.09 37.59 40.49 43.86 47.85 52.63 58.48 65.79 75.19 87.72
Max # of Modules for 600 Vdc 18 17 16 15 14 13 12 11 10 9 8 7 6
Use for DC/DC converters. The value calculated below must be less than DC/DC converter max DC input voltage (STEP 6).
B1. Module VOC (STEP 2) = ________ x # of modules per converter (STEP 6) ______ x 1.12 (If -1 ≤ TL ≤ -5°C, STEP 1) = _______ V
B2. Module VOC (STEP 2) = ________ x # of modules per converter (STEP 6) ______ x 1.14 (If -6 ≤ TL ≤ -10°C, STEP 1) = ______ V
Table 2. Largest Module VOC for Single-Module DC/DC Converter Configurations (with 80 V AFCI Cap) (CEC 690.7 and 690.11)
Max. Rated Module VOC (*1.12)
(Volts)30.4 33.0 35.7 38.4 41.1 43.8 46.4 49.1 51.8 54.5 57.1 59.8 62.5 65.2 67.9 70.5
Max. Rated Module VOC (*1.14)
(Volts)29.8 32.5 35.1 37.7 40.4 43.0 45.6 48.2 50.9 53.5 56.1 58.8 61.4 64.0 66.7 69.3
DC/DC Converter Max DC Input
(Step #6) (Volts)34 37 40 43 46 49 52 55 58 61 64 67 70 73 76 79
8) Maximum System DC Voltage from DC/DC Converters to Inverter — Only required if Yes in Step 6
Maximum System DC Voltage = _______________ Volts
9) Maximum Source Circuit Current
Is Module ISC below 9.6 Amps (Step 3)? Yes No (If No, use Comprehensive Standard Plan)
California Solar Permitting Guidebook28
10) Sizing Source Circuit Conductors
Source Circuit Conductor Size = Min. #10 AWG copper conductor, 90°C wet (USE-2, PV Wire, XHHW-2,
THWN-2, RHW-2)
For up to 8 conductors in roof-mounted conduit exposed to sunlight at least ½” from the roof covering (CEC 310)
Note: For over 8 conductors in the conduit or mounting height of lower than ½” from the roof, use Comprehensive Plan.
11) Are PV source circuits combined prior to the inverter? Yes No
If No, use Single Line Diagram 1 and proceed to Step 13.
If Yes, use Single Line Diagram 2 with Single Line Diagram 4 and proceed to Step 12.
Is source circuit OCPD required? Yes No
Source circuit OCPD size (if needed): 15 Amps
12) Sizing PV Output Circuit Conductors — If a combiner box will NOT be used (Step 11),
Output Circuit Conductor Size = Min. #6 AWG copper conductor
13) Inverter DC Disconnect
Does the inverter have an integrated DC disconnect? Yes No If Yes, proceed to step 14.
If No, the external DC disconnect to be installed is rated for ______ Amps (DC) and ______ Volts (DC)
14) Inverter Information
Manufacturer: ______________________________ Model: _______________________________
Max. Continuous AC Output Current Rating: _______ Amps
Integrated DC Arc-Fault Circuit Protection? Yes No (If No is selected, Comprehensive Standard Plan)
Grounded or Ungrounded System? Grounded Ungrounded
AC Information:
15) Sizing Inverter Output Circuit Conductors and OCPD
Inverter Output OCPD rating = ______ Amps (Table 3)
Inverter Output Circuit Conductor Size = ______ AWG (Table 3)
Table 3. Minimum Inverter Output OCPD and Circuit Conductor Size
Inverter Continuous Output Current Rating (Amps) (Step 14)12 16 20 24 28 32 36 40 48
Minimum OCPD Size (Amps)15 20 25 30 35 40 45 50 60
Minimum Conductor Size (AWG, 75°C, Copper)14 12 10 10 8 8 6 6 6
Integrated DC Arc-Fault Circuit Protection? Yes No (If No is selected, Comprehensive Standard Plan)
Grounded or Ungrounded System? Grounded Ungrounded
Part 3: PV Toolkit for Local Governments 29
16) Point of Connection to Utility
Only load side connections are permitted with this plan. Otherwise, use Comprehensive Standard Plan.
Is the PV OCPD positioned at the opposite end from input feeder location or main OCPD location? Yes No
If Yes, circle the Max Combined PV System OCPD(s) at 120% value as determined from Step 15 (or Step
S20), bus bar Rating, and Main OCPD as shown in Table 4.
If No, circle the Max Combined PV System OCPD(s) at 100% value as determined from Step 15 (or Step
S20), bus bar Rating, and Main OCPD as shown in Table 4.
Per 705.12(D)(2): [Inverter output OCPD size [Step #15 or S20] + Main OCPD Size] ≤ [bus size x (100%
or 120%)]
Table 4. Maximum Combined Supply OCPDs Based on Bus Bar Rating (Amps) per CEC 705.12(D)(2)
Bus Bar Rating 100 125 125 200 200 200 225 225 225
Main OCPD 100 100 125 150 175 200 175 200 225
Max Combined PV System OCPD(s)
at 120% of Bus Bar Rating
20 50 25 60*60*40 60*60*45
Max Combined PV System OCPD(s)
at 100% Bus Bar Rating
0 25 0 50 25 0 50 25 0
*This value has been lowered to 60 A from the calculated value to reflect 10 kW AC size maximum.
Reduction of the main breaker is not permitted with this plan. Otherwise, use Comprehensive
Standard Plan.
17 & 18 & 19) Labels and Grounding and Bonding
This content is covered by the labels on the next page and the Single Line Diagram(s). For background
information, refer to the Comprehensive Standard Plan.
California Solar Permitting Guidebook30
Solar PV Standard Plan — Simplified
Central/String Inverter Systems for One- and Two-Family Dwellings
Markings
CEC Articles 690 and 705 and CRC Section R331 require the following labels or markings be installed at these
components of the photovoltaic system:
EXPEDITED SOLAR PV STANDARD PLAN
Central/String Inverter Systems for One and Two Family Dwellings
3
CEC Articles 690 and 705 and CRC Section R331 require the following labels or markings be installed at these
components of the photovoltaic system:
WARNING
ELECTRIC SHOCK HAZARD. THE DC
CONDUCTORS OF THIS PHOTOVOLTAIC
SYSTEM ARE UNGROUNDED AND MAY
BE ENERGIZED
WARNING
INVERTER OUTPUT CONNECTION;
DO NOT RELOCATE THIS
OVERCURRENT DEVICE
CRC R331.2 and CFC 605.11.1
[Marked on junction/combiner boxes
and conduit every 10’]
WARNING: PHOTOVOLTAIC
POWER SOURCE
J/Box
PV SYSTEM AC DISCONNECT
RATED AC OUTPUT CURRENT -____AMPS
AC NORMAL OPERATING VOLTAGE ___VOLTS
M
A
C
INVERTER
D
C
WARNING
DUAL POWER SOURCES
SECOND SOURCE IS PHOTOVOLTAIC SYSTEM
RATED AC OUTPUT CURRENT-____AMPS AC
NORMAL OPERATING VOLTAGE ___VOLTS
WARNING
ELECTRIC SHOCK HAZARD
DO NOT TOUCH TERMINALS
TERMINALS ON BOTH LINE AND LOAD
SIDES MAY BE ENERGIZED IN THE
OPEN POSITION
PV SYSTEM DC DISCONNECT
RATED MAX POWER-POINT CURRENT-___ADC
RATED MAX POWER-POINT VOLTAGE-___VDC
SHORT CIRCUIT CURRENT-___ADC
MAXIMUM SYSTEM VOLTAGE-___VDC
CEC 705.12(D)(7)
[Not required if panelboard is rated not
less than sum of ampere ratings of all
overcurrent devices supplying it]
CEC 690.35(F)
[Only required for ungrounded systems]
CEC 690.54
CEC 690.53
CEC 690.17
CEC 690.54 & CEC 705.12(D)(4)
Code Abbreviations:
California Electrical Code (CEC)
California Residential Code (CRC)
California Fire Code (CFC)
WARNING
ELECTRIC SHOCK HAZARD
IF A GROUND FAULT IS INDICATED,
NORMALLY GROUNDED CONDUCTORS
MAY BE UNGROUNDED AND ENERGIZED
CEC 690.5(C)
[Normally already present on listed inverters]
Informational note: ANSI Z535.4 provides guidelines for the design of safety signs and labels for application to products. A phenolic
plaque with contrasting colors between the text and background would meet the intent of the code for permanency. No type size is
specified, but 20 point (3/8”) should be considered the minimum.
CEC 705.12 requires a permanent plaque or directory denoting all electric power sources on or in the premises.
Part 3: PV Toolkit for Local Governments 31
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#1
– NO
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C
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Co
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u
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w
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y
o
u
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l
o
c
a
l
A
H
J
a
n
d
/or
U
t
i
l
i
t
y
California Solar Permitting Guidebook32
So
l
a
r
P
V
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d
a
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P
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a
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—
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ST
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6
&
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&
12
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IN
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YE
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NO
PV
P
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YE
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NO
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YE
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NO
CO
N
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(US
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TA
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1 2 3 4 5 6 7 8 9 10 11
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MA
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8
6
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CB
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CB
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3
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11
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10
PV
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2
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)
++--
IN
V
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CONVERTERS
FO
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N
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B
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21
0
.5(C).
WH
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E
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N
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S
H
E
D
C
O
N
D
U
C
T
O
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A
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M
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.
+-
4
B1
C
A1
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#2
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P
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C
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C
/
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:
NO
N
-
C
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(
I
F
A
P
P
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C
A
B
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)
*
Co
n
s
u
l
t
w
i
t
h
y
o
u
r
l
o
c
a
l
A
H
J
a
n
d
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U
t
i
l
i
t
y
Part 3: PV Toolkit for Local Governments 33
Solar PV Standard Plan — Simplified
Central/String Inverter Systems for One- and Two-Family Dwellings
Supplemental Calculation Sheets for Inverter #2
(Only include if second inverter is used)
DC Information:
Module Manufacturer: __________________________ Model: ______________________________
S2) Module Voc (from module nameplate): ______ Volts S3) Module Isc (from module nameplate): ______ Amps
S4) Module DC output power under standard test conditions (STC) = ________ Watts (STC)
S5) DC Module Layout
Identify each source circuit
(string) for inverter 1 shown
on the roof plan with a Tag
(e.g. A,B,C,…)
Number of modules per
source circuit for inverter 1
Identify, by tag, which source circuits on the roof are to be
paralleled (if none, put N/A)
Combiner 1:
Combiner 2:
Total number of source circuits for inverter 1:
S6) Are DC/DC Converters used? Yes No If No, skip to Step S7. If Yes, enter info below.
DC/DC Converter Model #: __________________
Max DC Output Current: ____________________ Amps
Max # of DC/DC Converters in an Input Circuit: ___________
DC/DC Converter Max DC Input Voltage: ______ Volts
Max DC Output Current: ___________________ Volts
DC/DC Converter Max DC Input Power: _______ Watts
DE
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?
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(IF
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,
ST
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6
&
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RE
Q
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NO
PV
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?:
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CO
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(US
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8
6
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PV
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/DC
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)
++--
IN
V
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R
T
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R
DC/DC
CONVERTERS
FO
R
U
N
G
R
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S
Y
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:
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B
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T
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P
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21
0
.5(C).
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T
E
-FI
N
I
S
H
E
D
C
O
N
D
U
C
T
O
R
S
A
R
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N
O
T
P
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M
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T
T
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D
.
+-
4
B1
C
A1
SI
N
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L
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-LI
N
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D
I
A
G
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A
M
#2
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P
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:
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California Solar Permitting Guidebook34
S7) Maximum System DC Voltage — Use A1 or A2 for systems without DC/DC converters, and B1 or B2 with DC/DC Converters.
A1. Module VOC (STEP S2) = ____________ x # in series (STEP S5) ___________ x 1.12 (If -1 ≤ TL ≤ -5°C, STEP S1) = ____________ V
A2. Module VOC (STEP S2) = ____________ x # in series (STEP S5) ___________ x 1.14 (If -6 ≤ TL ≤ -10°C, STEP S1) = ___________ V
Table 1. Maximum Number of PV Modules in Series Based on Module Rated VOC for 600 Vdc Rated Equipment (CEC 690.7)
Max. Rated Module VOC (*1.12)
(Volts)29.76 31.51 33.48 35.71 38.27 41.21 44.64 48.70 53.57 59.52 66.96 76.53 89.29
Max. Rated Module VOC (*1.14)
(Volts)29.24 30.96 32.89 35.09 37.59 40.49 43.86 47.85 52.63 58.48 65.79 75.19 87.72
Max # of Modules for 600 Vdc 18 17 16 15 14 13 12 11 10 9 8 7 6
Use for DC/DC converters. The value calculated below must be less than DC/DC converter max DC input voltage (STEP S6).
B1. Module VOC (STEP S2) = ________ x # of modules per converter (STEP S6) ______ x 1.12 (If -1 ≤ TL ≤ -5°C, STEP S1) = _______ V
B2. Module VOC (STEP S2) = ________ x # of modules per converter (STEP S6) ______ x 1.14 (If -6 ≤ TL ≤ -10°C, STEP S1) = ______ V
Table 2. Largest Module VOC for Single-Module DC/DC Converter Configurations (with 80 V AFCI Cap) (CEC 690.7 and 690.11)
Max. Rated Module VOC (*1.12)
(Volts)30.4 33.0 35.7 38.4 41.1 43.8 46.4 49.1 51.8 54.5 57.1 59.8 62.5 65.2 67.9 70.5
Max. Rated Module VOC (*1.14)
(Volts)29.8 32.5 35.1 37.7 40.4 43.0 45.6 48.2 50.9 53.5 56.1 58.8 61.4 64.0 66.7 69.3
DC/DC Converter Max DC Input
(Step 6) (Volts)34 37 40 43 46 49 52 55 58 61 64 67 70 73 76 79
S8) Maximum System DC Voltage from DC/DC Converters to Inverter — Only required if Yes in Step S6
Maximum System DC Voltage = _______________ Volts
S9) Maximum Source Circuit Current
Is Module ISC below 9.6 Amps (Step S3)? Yes No (If No, use Comprehensive Standard Plan)
S10) Sizing Source Circuit Conductors
Source Circuit Conductor Size = Min. #10 AWG copper conductor, 90°C wet (USE-2, PV Wire, XHHW-2,
THWN-2, RHW-2)
For up to 8 conductors in roof-mounted conduit exposed to sunlight at least ½” from the roof covering (CEC 310)
Note: For over 8 conductors in the conduit or mounting height of lower than ½” from the roof, use Comprehensive
Plan.
S11) Are PV source circuits combined prior to the inverter? Yes No
If No, use Single Line Diagram 1 and proceed to Step S13.
If Yes, use Single Line Diagram 2 with Single Line Diagram 4 and proceed to Step S12.
Is source circuit OCPD required? Yes No
Source circuit OCPD size (if needed): 15 Amps
S12) Sizing PV Output Circuit Conductors — If a combiner box will NOT be used (Step S11),
Output Circuit Conductor Size = Min. #6 AWG copper conductor
S13) Inverter DC Disconnect
Does the inverter have an integrated DC disconnect? Yes No If Yes, proceed to Step S14.
If No, the external DC disconnect to be installed is rated for ______ Amps (DC) and ______ Volts (DC)
Part 3: PV Toolkit for Local Governments 35
S14) Inverter Information
Manufacturer: ______________________________ Model: _______________________________
Max. Continuous AC Output Current Rating: _______ Amps
Integrated DC Arc-Fault Circuit Protection? Yes No (If No is selected, Comprehensive Standard Plan)
Grounded or Ungrounded System? Grounded Ungrounded
AC Information:
S15) Sizing Inverter Output Circuit Conductors and OCPD
Inverter Output OCPD rating = ______ Amps (Table 3)
Inverter Output Circuit Conductor Size = ______ AWG (Table 3)
Table 3. Minimum Inverter Output OCPD and Circuit Conductor Size
Inverter Continuous Output Current Rating (Amps) (Step 14)12 16 20 24 28 32 36 40 48
Minimum OCPD Size (Amps)15 20 25 30 35 40 45 50 60
Minimum Conductor Size (AWG, 75°C, Copper)14 12 10 10 8 8 6 6 6
Load Center Calculations
(Omit if a load center will not be installed for PV OCPDs)
S20) Load Center Output:
Calculate the sum of the maximum AC outputs from each inverter.
Inverter #1 Max Continuous AC Output Current Rating [STEP S14] _______ × 1.25 = _______ Amps
Inverter #2 Max Continuous AC Output Current Rating [STEP S14] _______ × 1.25 = _______ Amps
Total inverter currents connected to load center (sum of above) = _______ Amps
Conductor Size: ______ AWG
Overcurrent Protection Device: ______ Amps
Load center bus bar rating: ______ Amps
The sum of the ampere ratings of overcurrent devices in circuits supplying power to a bus bar or conductor
shall not exceed 120 percent of the rating of the bus bar or conductor.
California Solar Permitting Guidebook36
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Part 3: PV Toolkit for Local Governments 37
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California Solar Permitting Guidebook38
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Part 3: PV Toolkit for Local Governments 39
TOOLKIT DOCUMENT #4
Solar PV Standard Plan — Simplified
Microinverter and ACM Systems for
One- and Two-Family Dwellings
Your City
logo here
SCOPE: Use this plan ONLY for systems using utility-interactive Microinverters or AC Modules (ACM) not exceeding a combined system
AC inverter output rating of 10 kW, with a maximum of 3 branch circuits, one PV module per inverter and with PV module ISC maximum
of 10-A DC, installed on a roof of a one- or two-family dwelling or accessory structure. The photovoltaic system must interconnect to a
single-phase AC service panel of 120/240 Vac with service panel bus bar rating of 225 A or less. This plan is not intended for bipolar
systems, hybrid systems or systems that utilize storage batteries, charge controllers or trackers. Systems must be in compliance with
current California Building Standards Codes and local amendments of the authority having jurisdiction (AHJ). Other articles of the
California Electrical Code (CEC) shall apply as specified in section 690.3.
MANUFACTURER’S SPECIFICATION SHEETS MUST BE PROVIDED for proposed inverters, modules, combiner/junction boxes and racking
systems. Installation instructions for bonding and grounding equipment shall be provided and local AHJs may require additional details.
Listed and labeled equipment shall be installed and used in accordance with any instructions included in the listing or labeling (CEC
110.3). Equipment intended for use with PV system shall be identified and listed for the application CEC 690.4(D).
Applicant and Site Information
Job Address: ___________________________________________ Permit #: __________________________
Contractor/ Engineer Name: ______________________________ License # and Class: __________________
Signature: ___________________________ Date: _____________ Phone Number: _____________________
1. General Requirements and System Information
Microinverter AC Module (ACM)
Number of PV modules installed: __________ Number of ACMs installed: __________
Number of Microinverters installed: __________ Note: Listed Alternating-Current Module (ACM) is defined
in CEC 690.2 and installed per CEC 690.6
1.1 Number of Branch Circuits, 1, 2 or 3: __________
1.2 Actual number of Microinverters or ACMs per branch circuit: 1 ________ 2.________ 3._______
1.3 Total AC system power rating = (Total Number of Microinverters or ACMs) * (AC inverter power output)
= __________ Watts
1.4 Lowest expected ambient temperature for this plan in Table 1: For -1 to -5°C use 1.12 or for -6 to -10°C
use 1.14 correction factors.
1.5 Average ambient high temperature for this plan: = +47°C
Note: For lower expected ambient or higher average ambient high temperatures, use Comprehensive Standard Plan.
2. Microinverter or ACM Information and Ratings
Microinverters with ungrounded DC inputs shall be installed in accordance with CEC 690.35.
Microinverter or ACM Manufacturer: _____________________________
Model: ______________________________________________________
2.1 Rated (continuous) AC output power: __________ Watts
California Solar Permitting Guidebook40
2.2 Nominal AC voltage rating: __________ Volts
2.3 Rated (continuous) AC output current: __________ Amps
If installing ACMs, skip [STEPS 0]
2.4 Maximum DC input voltage rating: __________ Volts (limited to 79 V, otherwise use the Comprehensive
Standard Plan)
2.5 Maximum AC output overcurrent protection device (OCPD) ___________ Amps
2.6 Maximum number of Microinverters or ACMs per branch circuit: ___________
3. PV Module Information
(If installing ACMs, skip to [STEP 4])
PV Module Manufacturer: _______________________________________________
Model: _______________________________________________________________
Module DC output power under standard test conditions (STC) = __________ Watts
3.1 Module VOC at STC (from module nameplate): __________ Volts
3.2 Module ISC at STC (from module nameplate): ___________ Amps
3.3 Adjusted PV Module DC voltage at minimum temperature = [Table 1] _____________ [cannot exceed
Step 0]
Table 1. Module VOC at STC Based on Inverter Maximum DC Input Voltage Derived from CEC 690.7
Microinverter Max. DC Input
[STEP 0] (Volts)34 37 40 43 46 49 52 55 58 61 64 67 70 73 76 79
Max. Module VOC @ STC,
1.12 (-1 to -5°C) Correction
Factor (Volts)
30.4 33.0 35.7 38.4 41.1 43.8 46.4 49.1 51.8 54.5 57.1 59.8 62.5 65.2 67.9 70.5
Max. Module VOC @ STC,
1.14 (-6 to -10°C) Correction
Factor (Volts)
29.8 32.5 35.1 37.7 40.4 43.0 45.6 48.2 50.9 53.5 56.1 58.8 61.4 64.0 66.7 69.3
4. Branch Circuit Output Information
Fill in [Table 3] to describe the branch circuit inverter output conductor and OCPD size. Use [Table 2] for
determining the OCPD and Minimum Conductor size.
Table 2. Branch Circuit OCPD and Minimum Conductor Size*
Circuit Current (Amps)Circuit Power (Watts)OCPD (Amps)Minimum Conductor Size
(AWG)
Minimum Metal Conduit
Size for 6 Current Carrying
Conductors
12 2880 15 12 ¾”
16 3840 20 10 ¾”
20 4800 25 8 1”
24 5760 30 8 1”
*CEC 690.8 and 210.19 (A)(1) Factored in Table 2, Conductors are copper, insulation must be 90°C wet-rated. Table 2 values are based on maximum
ambient temperature of 69°C, which includes 22°C adder, exposed to direct sunlight, mounted > 0.5 inches above rooftop, ≤ 6 current carrying
conductors (3 circuits) in a circular raceway. Otherwise use Comprehensive Standard Plan.
Part 3: PV Toolkit for Local Governments 41
Table 3. PV Array Configuration Summary
Branch 1 Branch 2 Branch 3
Number of Microinverters or ACMs [Step 0]
Selected Conductor Size [Table 2] (AWG)
Selected Branch and Inverter Output OCPD [Table 2]
5. Solar Load Center (if used)
5.1 Solar Load Center is to have a bus bar rating not less than 100 Amps. Otherwise use Comprehensive
Standard Plan.
5.2 Circuit Power see [STEP 0] =___________ Watts
5.3 Circuit Current = (Circuit Power) / (AC voltage) = __________ Amps
Table 4. Solar Load Center and Total Inverter Output OCPD and Conductor Size**
Circuit Current (Amps)Circuit Power (Watts)OCPD (Amps)Minimum Conductor Size
(AWG)
Minimum Metal Conduit
Size
24 5760 30 10 ½”
28 6720 35 8 ¾”
32 7680 40 8 ¾”
36 8640 45 8 ¾”
40 9600 50 8 ¾”
41.6 ≤ 10000 60 6 ¾”
**CEC 690.8 and 210.19 (A)(1) Factored in Table 4, Conductors are copper, insulation must be 90°C wet-rated. Table 4 values are based on maximum
ambient temperature of 47°C (no rooftop temperature adder in this calculation), ≤ 3 current carrying conductors in a circular raceway. Otherwise use
Comprehensive Standard Plan.
6. Point of Connection to Utility:
6.1 Load Side Connection only! Otherwise use the Comprehensive Standard Plan.
6.2 Is the PV OCPD positioned at the opposite end from input feeder location or main OCPD location?
Yes No (If No, then use 100% row in Table 5)
6.3 Per 705.12(D)(2): (Combined inverter output OCPD size + Main OCPD size) ≤ [bus bar size × (100% or
120%)]
Table 5. Maximum Combined Inverter Output CIrcuit OCPD
Bus Bar Size (Amps)100 125 125 200 200 200 225 225 225
Main OCPD (Amps)100 100 125 150 175 200 175 200 225
Maximum Combined Inverter OCPD with 120% of bus bar
rating (Amps)
20 50 25 60†60†40 60†60†45
Maximum Combined Inverter OCPD with 100% of bus bar
rating (Amps)
0 25 0 50 25 0 50 25 0
†This plan limits the maximum system size to less than 10 kW, therefore the OCPD size is limited to 60 A. Reduction of Main Breaker is not permitted
with this plan.
California Solar Permitting Guidebook42
7. Grounding and Bonding
Check one of the boxes for whether system is grounded or ungrounded: Grounded Ungrounded
For Microinverters with a grounded DC input, systems must follow the requirements of GEC (CEC 690.47) and
EGC (CEC 690.43).
For ACM systems and Microinverters with ungrounded a DC input follow the EGC requirements of (CEC 690.43).
8. Markings
Informational note: ANSI Z535.4 provides guidelines for the design of safety signs and labels for application to
products. A phenolic plaque with contrasting colors between the text and background would meet the intent of
the code for permanency. No type size is specified, but 20 point (3/8”) should be considered the minimum.
M
NOTE: CEC 705.10 requires a permanent plaque or
directory denoting all electric power sources on or in the
premesis.
CEC 690.54
CEC 690.54 & CEC 705.12 (D)(4)
WARNING
DUAL POWER SOURCES
SECOND SOURCE IS PHOTOVOLTAIC SYSTEM
RATED AC OUTPUT CURRENT ______ AMPS AC
NORMAL OPERATING VOLTAGE ______ VOLTS
WARNING
INVERTER OUTPUT CONNECTION
DO NOT RELOCATE THIS
OVERCURRENT DEVICE
AC
DC
PV
AC
DC
PV
AC
DC
PV
AC
DC
PV
Optional AC Disconnect per AHJ PV SYSTEM AC DISCONNECT
SECOND SOURCE IS PHOTOVOLTAIC SYSTEM
RATED AC OUTPUT CURRENT ______ AMPS AC
NORMAL OPERATING VOLTAGE ______ VOLTS
Optional Solar Load Center
AC
DC
PV
AC
DC
PV
AC
DC
PV
AC
DC
PV
AC
..
.
CEC 705.12 (D)(7)
Part 3: PV Toolkit for Local Governments 43
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California Solar Permitting Guidebook44
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Part 3: PV Toolkit for Local Governments 45
TOOLKIT DOCUMENT #5
Structural Criteria for Residential
Rooftop Solar Energy Installations
Yo ur City
logo here
Use of this document
This toolkit document includes a one-page list of structural criteria for over-the-counter or online approval, as
well as attached tables and figures that supplement the criteria and explain their use.
This document applies to flush-mounted solar arrays installed on the roofs of wood-framed one- and two-
family dwellings. “Flush-mounted” means the modules are installed parallel to, and relatively close to, the roof
surface (see the “Solar Array Check” section of the Structural Criteria for specific qualifying requirements).
This list is intended to be a simple pre-installation check to gain reasonable assurance that the design of the
solar array complies with the structural provisions of the 2013 California Building Code (CBC) and 2013
California Residential Code (CRC). It is not intended to provide post-installation inspection criteria.
Currently Used Expedited Solar Permitting Approaches
This document is intended for jurisdictions without an expedited process for residential solar structural
permitting, and is not intended to replace or supplant procedures for jurisdictions with an expedited process
already in place. Good examples from jurisdictions with provisions for expedited structural permitting include
the City of Los Angeles, which exempts residential solar installations from structural permitting if five simple
requirements are met, and the East Bay Green Corridor’s streamlined solar permitting process, which uses
structural criteria tailored to typical conditions for that consortium of nine cities.
Regional and Site Assumptions
This document is based on the following regional and site assumptions:
• The dwelling is located in a ZERO snow load area (see Map 1).
• The dwelling is not in Wind Exposure D (within 200 yards of the ocean or a large coastal bay).
• If in Wind Exposure B (urban, suburban or wooded areas), the dwelling may be located:
–in a Special Wind Region (see Map 2) with design wind speeds between 110 and 130 mph, or
–on a tall hill, provided average slope is no steeper than 15%.
• If in Wind Exposure C (within 500 yards of large open fields or grasslands), the dwelling is:
–in a standard 110 mph design wind speed region, and
–not on a hill with a grade steeper than 5%.
Additional Options
The Chief Building Official (CBO) may consider adding rows to the structural criteria, based on personal
judgment and their jurisdiction’s conditions and history. Possible additional questions include:
• Regional and Site Checks
–If the jurisdiction is in a mixed snow load area, with zero snow load only at lower elevations, consider
asking “is the dwelling lower than elevation ___ feet?”
(Introductory text provided for jurisdiction’s reference only. Do not attach to Criteria that follow.)
California Solar Permitting Guidebook46
–If the jurisdiction is in a coastal region, consider asking “is the dwelling farther than 200 yards from
the ocean or a large coastal bay?” to verify the dwelling is not in Wind Exposure D.
–If the jurisdiction is in a Special Wind Region with design wind speeds between 115 and 130 mph,
consider verifying that the dwelling is in Wind Exposure B by asking “is the dwelling in an urban,
suburban or wooded area, and not within 500 yards of open fields and grasslands?”
–If the jurisdiction is in a Special Wind Region with design wind speeds between 115 and 130 mph,
consider verifying that there are no significant topographic wind speed-up effects by asking “is the
dwelling in a relatively flat area (grade less than 5%) and not within 500 yards of the crest of a tall hill?”
• Roof Check
–Based on the jurisdiction’s one- and two-family housing stock and code compliance history, many
CBOs will find it reasonable to assume that most dwellings’ roof structures were designed to the
building code in effect at the time the houses were built. If so, the roof structure code compliance
check consists of the Contractor’s visual roof audit, checking for unusual sagging or deterioration,
without requiring additional measurements of existing rafters to check against span tables.
–For CBOs of jurisdictions with evidence of structurally deficient one- and two-family housing stock
or poor structural code compliance history, the CBO may elect to add the rafter span check option
described in the criteria.
The Structural Toolkit and CRC Wind Speeds
The 2013 CRC contains an inconsistency related to wind speeds. Despite referencing ASCE 7-10 as its
standard, the 2013 CRC’s text and tables use outdated ASCE 7-05 wind speeds. Under the old ASCE 7-05
/ CBC 2010, the basic design wind speed in most regions of the state was 85 mph (max. 3 second gust in
50 years). Under ASCE 7-10 / CBC 2013, the design wind speed has increased to 110 mph (max. 3 second
gust in 700 years). Despite the different definitions of wind speed, design wind pressures remain essentially
unchanged.
Because the Toolkit’s structural document is intended to be forward looking, all wind speeds in the Toolkit
document are based on the ASCE 7-10. This is clearly stated in the caption to the state wind speed map, and in
the Table 1 footnotes. This anticipates an obvious and expected correction to the CRC; otherwise the Toolkit
would become immediately outdated when the CRC is amended to change the base design wind speed from 85
mph to 110 mph.
2013 CRC text (ASCE 7-05) wind speeds equivalent to the 2013 CRC and CBC Reference Standard (ASCE
7-10) are shown below. See ASCE 7-10 Table C26.5-6 for additional information.
2013 CRC text 2013 CRC and CBC Referenced Standard
ASCE 7-05 ASCE 7-10
85 mph 110 mph
90 mph 115 mph
95 mph 120 mph
100 mph 126 mph
105 mph 133 mph
(Introductory text provided for jurisdiction’s reference only. Do not attach to Criteria that follow.)
Part 3: PV Toolkit for Local Governments 47
Structural Technical Appendix
This toolkit document is supported by a Structural Technical Appendix that describes the technical analysis
behind these criteria, which are based on structural engineering principles and the California Building
and Residential Codes. The Technical Appendix also provides some additional guidance to address non-
conforming items, such as when an anchor layout is not based on a solar support component manufacturer’s
guidelines, or when a coastal site is located within 200 yards of the ocean (Exposure D). This document can be
found online.
Probability of Code Compliance
The Structural Technical Appendix includes a section that examines the probabilities associated with the
assumptions behind Table 1 that allows six feet cross-slope anchor spacing in some circumstances. That
statistical analysis estimates that the probability of code noncompliance for six feet anchor spacing is only 2 in
a thousand installations (0.2%). Note that probability of structural failure is orders of magnitude lower than
the probability of code noncompliance.
(Introductory text provided for jurisdiction’s reference only. Do not attach to Criteria that follow.)
California Solar Permitting Guidebook48
31
Map 2. California Ground Snow Load Map (Ref: ASCE 7-10).
Numbers in parentheses represent the upper elevation limits in feet for the ground snow load in psf
listed below the elevation. Example: (2400) ZERO in the south San Francisco bay area indicates that
zero ground snow loads occur from sea level up to an elevation of 2400 feet. CS indicates "Case
Studies" where extreme local variations in ground snow loads occur. Non-zero snow load areas and
Case Study (CS) areas are excluded from the Expedited Solar Permitting Process. See the Technical
Appendix for additional information.
Map 1. California Ground Snow Load Map (Ref: ASCE 7-10).
The numbers in parentheses represent the upper elevation limits in feet for the ground snow load in psf listed
below the elevation. Example: (2400) ZERO in the South San Francisco bay area indicates that zero ground
snow loads occur from sea level up to an elevation of 2400 feet. CS indicates “Case Studies” where extreme
local variations in ground snow loads occur. Non-zero snow load areas and Case Study (CS) areas are excluded
from the use of this structural toolkit document. See the Technical Appendix for additional information.
(Map provided for jurisdiction’s reference only. Do not attach to Criteria that follow.)
Part 3: PV Toolkit for Local Governments 49
30
Map 1. California Design Wind Speed Map (Ref: ASCE 7-10).
As shown on the map, typical design wind speed is 110 mph (3 second gust in 700 years). The grey
shaded areas on the map indicate special wind regions with higher wind speeds that are excluded
from the Expedited Solar Permitting Process. See the Technical Appendix for additional information.
Map 2. California Design Wind Speed Map (Ref: ASCE 7-10).
The number outside the parentheses represents the design wind speed in mph. Typical design wind speed is
110 mph. The grey shaded areas on the map indicate “special wind regions” where higher wind speeds may
apply. When the project is in a grey shaded area, contact the local building department for the design wind
speed.
(Map provided for jurisdiction’s reference only. Do not attach to Criteria that follow.)
California Solar Permitting Guidebook50
STRUCTURAL CRITERIA FOR RESIDENTIAL FLUSH-MOUNTED SOLAR ARRAYS
1. ROOF CHECKS
A. Visual Review/Contractor’s Site Audit of Existing Conditions:
1) Is the roof a single roof without a reroof overlay? Y N
2) Does the roof structure appear structurally sound, without signs of alterations
or significant structural deterioration or sagging, as illustrated in Figure 1? Y N
B. Roof Structure Data:
1) Measured roof slope (e.g. 6:12): ________:12
2) Measured rafter spacing (center-to-center): _______ inch
3) Type of roof framing (rafter or manufactured truss): Rafter Truss
2. SOLAR ARRAY CHECKS
A. Flush-mounted Solar Array:
1) Is the plane of the modules (panels) parallel to the plane of the roof? Y N
2) Is there a 2” to 10” gap between underside of module and the roof surface? Y N
3) Modules do not overhang any roof edges (ridges, hops, gable ends, eaves)? Y N
B. Do the modules plus support componenets weigh no more than:
4 psf for photovoltaic arrays or 5 psf for solar thermal arrays? Y N
C. Does the array cover no more than half of the toal roof area (all roof planes)? Y N
D. Are solar support component manufacturer’s project-specific completed worksheets,
tables with relevant cells circled, or web-based calculator results attached? Y N
E. Is a roof plan of the module and anchor layout attached? (see Figure 2) Y N
F. Downward Load Check (Anchor Layout Check):
1) Proposed anchor horizontal spacing (see Figure 2): ____’ - ____”ft-in
2) Horizontal anchor spacing per Table 1: ____’ - ____”ft-in
3) Is proposed anchor horizontal spacing less than Table 1 spacing? Y N
G. Wind Uplift Check (Anchor Fastener Check):
1) Anchor fastener data (see Figure 3):
a. Diameter of lag screw, hanger bolt or self-drilling screw: _______ inch
b. Embedment depth of rafter: _______ inch
c. Number of screws per anchor (typically one): _______
d. Are 5/16” diameter lag screws with 2.5” embedment into the rafter
used, OR does the anchor fastener meet the manufacturer’s guidelines? Y N
3. SUMMARY
A. All items above are checked YES. No additional calculations are required.
B. One or more items are checked NO. Attach project-specific drawings and calculations stamped and signed by a
California-licensed Civil or Structural Engineer.
Job Address: ___________________________________________ Permit #: ________________________
Contractor/Installer: _____________________________________ License # & Class: _________________
Signature: ____________________________ Date: ____________ Phone #: ________________________
Optional Additional Rafter Span Check Criteria
[ At option of CBO, insert rows (4) to (7) below into table above after row 1.B.(3) ]
1. ROOF CHECKS
B. Roof Structure Data:
4) Measured rafter size (e.g. 13/4 x 33/4, not 2x4): ____ x ____ inch
5) Measured rafter horizontal span (see Figure 4): ____’ - ____”ft-in
6) Horizontal rafter span per Table 2: ____’ - ____”ft-in
7) Is measured horizontal rafter span less than Table 2 span? Y N Truss
(Jurisdictions may delete “Optional Additional Rafter Span Check” at bottom of this page, or incorporate into main list of Structural Criteria above)
Part 3: PV Toolkit for Local Governments 51
Table 1. Maximum Horizontal Anchor Spacing
Roof Slope Rafter Spacing
16” o.c.24” o.c.32” o.c.
Photovoltaic Arrays (4 psf max)
Flat to 6:12 0° to 26°5’-4”6’-0”5’-4”
7:12 to 12:12 27° to 45°1’-4”2’-0”2’-8”
13:12 to 24:12 46° to 63°1’-4”2’-0”2’-8”
Solar Thermal Arrays (5 psf max)
Flat to 6:12 0° to 26°4’-0”4’-0”5’-4”
7:12 to 12:12 27° to 45°1’-4”2’-0”2’-8”
13:12 to 24:12 46° to 63°Calc. Req’d Calc. Req’d Calc. Req’d
Solar support component manufacturer’s guidelines may be relied upon to ensure the array above the roof is
properly designed, but manufacturer’s guidelines typically do NOT check to ensure that the roof itself can support
the concentrated loads from the solar array. Table 1 assumes that the roof complied with the building code in
effect at the time of construction, and places limits on anchor horizontal spacing to ensure that a roof structure is
not overloaded under either downward loads or wind uplift loads. Note 4 below lists the basic assumptions upon
which this table is based.
Table 1 Notes:
1. Anchors are also known as “stand-offs”, “feet”, “mounts” or “points of attachment”. Horizontal anchor
spacing is also known as “cross-slope” or “east-west” anchor spacing (see Figure 2).
2. If anchors are staggered from row-to-row going up the roof, the anchor spacing may be twice that shown
above, but no greater than 6’-0”.
3. For manufactured plated wood trusses at slopes of flat to 6:12, the horizontal anchor spacing shall not
exceed 4’-0” and anchors in adjacent rows shall be staggered.
4. This table is based on the following assumptions:
• The roof structure conformed to building code requirements at the time it was built.
• The attached list of criteria are met.
• Mean roof height is not greater than 40 feet.
• Roof sheathing is at least 7/16” thick oriented strand board or plywood. 1x skip sheathing is acceptable.
• If the dwelling is in Wind Exposure B (typical urban, suburban or wooded areas farther than 500
yards from large open fields), no more than one of the following conditions apply:
– The dwelling is located in a special wind region with design wind speed between 115 and 130
mph per ASCE 7-10, or
– The dwelling is located on the top half of a tall hill, provided average slope steeper is less than
15%.
• If the dwelling is In Wind Exposure C (within 500 yards of large open fields or grasslands), all of the
following conditions apply:
– Design wind speed is 110 mph or less (not in a Special Wind Region), and
– The dwelling is not located on the top half of a tall hill.
• The solar array displaces roof live loads (temporary construction loads) that the roof was originally
designed to carry.
• The Structural Technical Appendix provides additional information about analysis assumptions.
California Solar Permitting Guidebook52
Table 2. Roof Rafter Maximum Horizontal Span (feet - inches)1
Assumed
Vintage
Nominal
Size
Actual
Size
Non-Tile Roof2 Tile Roof3
Rafter Spacing
16” o.c.24” o.c.32” o.c.16” o.c.24” o.c.32” o.c.
Post-1960
2x4 1½”x3½”9’-10”8’-0”6’-6”8’-6”6’-11”5’-6”
2x6 1½”x5½”14’-4”11’-9”9’-6”12’-5”10’-2”8’-0”
2x8 1½”x7¼”18’-2”14’-10”12’-0”15’-9”12’-10”10’-3”
Pre-1960
2x4 1¾”x3¾”11’-3”9’-9”7’-9”10’-3”8’-6”6’-9”
2x6 1¾”x5¾”17’-0”14’-0”11’-3”14’-9”12’-0”9’-9”
2x8 1¾”x7¾”22’-3”18’-0”14’-6”19’-0”15’-6”12’-6”
Beyond a visual review by the Contractor checking for unusual sagging or deterioration, some CBOs may want
additional assurance that the roof structure complies with structural building code requirements. Table 2 is an
optional table some CBOs may elect to use to provide additional assurance by requiring a check of existing roof
rafter spans, and supports optional criteria 1.B.5 and 1.B.6. For post-1960 construction, these span tables match
the rafter span tables found in the 2013 California Building and Residential codes. For pre-1960 construction, the
rafter span tables are based on structural calculations with lumber sizes and wood species & grade appropriate for
older construction. Note 5 below lists the basic assumptions upon which this table is based.
Table 2 Notes:
1. See Figure 4 for definition of roof rafter maximum horizontal span.
2. “Non-tile Roof” = asphalt shingle, wood shingle & wood shake, with an assumed roof assembly weight of
10 psf.
3. “Tile Roof” = clay tile or cement tile, with an assumed roof assembly weight of 20psf
4. Unaltered manufactured plated-wood trusses may be assumed to be code compliant and meet intent of
Table 2.
5. This table is based on the following assumptions:
• Span/deflection ratio is equal to or greater than 180.
• For post-1960 construction, wood species and grade is Douglas Fir-Larch No. 2.
• For pre-1960 construction, wood species and grade is Douglas Fir-Larch No. 1.
• Other wood species and/or grade are also acceptable if allowable bending stress is equal or greater to
that listed above.
(Attach Table 2 ONLY if the Optional Additional Rafter Span Check is added to the list of Structural Criteria)
Part 3: PV Toolkit for Local Governments 53
Figure 1. Roof Visual Structural Review (Contractor’s Site Audit) of Existing Conditions.
The site auditor should verify the following:
1. No visually apparent disallowed rafter holes, notches and truss modifications as shown above.
2. No visually apparent structural decay or un-repaired fire damage.
3. Roof sag, measured in inches, is not more than the rafter or ridge beam length in feet divided by 20.
Rafters that fail the above criteria should not be used to support solar arrays unless they are first strengthened.
Figure 2. Sample Solar Panel Array and Anchor Layout Diagram (Roof Plan).
34
Figure 3. Sample Photovoltaic Module and Anchor Layout Diagram.
Figure 4. Typical Anchor with Lag Screw Attachment.
32
Figure 1. Roof Visual Structural Review of Existing Conditions.
1. No visually apparent disallowed rafter holes, notches and truss modifications as shown above.
2. No visually apparent structural decay or un-repaired fire damage.
3. Roof sag, when measured in inches, not more than the rafter length in feet divided by 20.
4. Rafters that fail the above criteria shall not be used to support solar arrays unless they are first
strengthened.
California Solar Permitting Guidebook54
Figure 3. Typical Anchor with Lag Screw Attachment.
Figure 4. Definition of Rafter Horizontal Span.
34
Figure 3. Sample Photovoltaic Module and Anchor Layout Diagram.
Figure 4. Typical Anchor with Lag Screw Attachment.
(Attach Figure 4 ONLY if the Optional Additional Rafter Span Check is added to the list of Structural Criteria)
Part 3: PV Toolkit for Local Governments 55
This memorandum of understanding (MOU) formalizes coordination by local agencies regarding plan review
and inspection services for solar photovoltaic installations.
Note: Language in CAPS below indicates where local jurisdiction needs to provide information specific to the jurisdiction.
This agreement is made at [LOCATION], California, by and between [FIRE AUTHORITY] and [BUILDING
AUTHORITY].
Recitals
WHEREAS, Sections 1.8.2.1 and 1.11.2 of the currently adopted version of the California Residential
Code charges the local building authority and local fire authority with the responsibility of enforcement of
residential building standards within the jurisdictions boundaries; and
WHEREAS, the [FIRE AUTHORITY] desires the [BUILDING AUTHORITY] to perform these services on its
behalf subject to the following terms and conditions; and
WHEREAS, the [BUILDING AUTHORITY] is willing to perform said services provided it can charge and
collect all fees for services rendered subject to the following terms and conditions.
Services Agreement
1. Services The [BUILDING AUTHORITY] shall conduct the services outlined in Exhibit A for the
review of plans and inspection of solar photo voltaic systems within the [JURISDICTION] boundaries
during the term of this agreement.
2. Term The term of this agreement shall commence on ______________, and shall be for
_______________. The term of this agreement may be extended upon agreement of [FIRE
AUTHORITY] and the [BUILDING AUTHORITY].
3. Plan Review and Inspection Fees/Charges The [BUILDING AUTHORITY] shall charge
and collect its standard fees for plan review and inspection. The [FIRE AUTHORITY] shall receive no
portion of said fees.
4. Facilities, Equipment and Other Materials The [BUILDING AUTHORITY] shall, at its cost
and expense, furnish all facilities, equipment and other materials that may be required for furnishing
services pursuant to this agreement.
5. No Agency No agency relationship is created by this agreement.
6. Records The [BUILDING AUTHORITY] shall maintain, at all times, complete detailed records with
regard to work performed under this agreement. The [FIRE AUTHORITY] shall have the right to
inspect said records with reasonable notice to the county. All such records shall be maintained by the
[BUILDING AUTHORITY] in its [OFFICE LOCATION] offices.
TOOLKIT DOCUMENT #6
[ADMINISTERING AGENCIES] Agreement Number: [NUMBER]
MOU (Memorandum of Understanding)
Regarding Solar Photovoltaic Plan Review
and Inspection Services
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California Solar Permitting Guidebook56
7. Insurance It is agreed that each party shall maintain at all times during the performance of this
agreement insurance coverage or self-insurance in the amount of not less than [DOLLAR AMOUNT]
to cover all of its operations, including general liability, automobile liability and workers’ compensation.
8. Indemnification The [BUILDING AUTHORITY] shall indemnify, defend and hold harmless
the [FIRE AUTHORITY] and its elected and appointed officials, employees, agents and contractors
(collectively, “indemnities”) from and against any and all loss, liability, cost, claim, cause of action,
demand, judgment, expense, (including reasonable attorneys’ fees) or damage (collectively “claims”)
arising from or related to [BUILDING AUTHORITY] performance or failure to perform its obligations
pursuant to this agreement, except to the extent the same are attributable to the gross negligence or
willful misconduct of the Indemnities. The [FIRE AUTHORITY] shall indemnify, defend and hold
harmless the [BUILDING AUTHORITY] and its elected and appointed officials, employees, agents and
contractors (collectively, “building indemnities”) from and against any and all claims arising from or
related to the [BUILDING AUTHORITY] performance or failure to perform its obligations pursuant
to this agreement, except to the extent the same are attributable to the gross negligence or willful
misconduct of building indemnities.
9. Entirety of Agreement – Modifications This agreement contains the entire agreement of the
[FIRE AUTHORITY] and the [BUILDING AUTHORITY] with respect to the subject matter hereof,
and no other agreement, statement, or promise made by any party, or to any employee, officer or agent
of any party, which is not contained in this agreement, shall be binding or valid.
10. Early Termination Either party may serve notice of early termination of this agreement pursuant
to Section 11 below. Upon termination of this agreement, the [FIRE AUTHORITY] shall take over all
plan review and inspections covered by this agreement. For plan review and/or inspections that are in
process at the time of termination, the county shall complete these.
11. Notice Any notice or demand desired or required to be given hereunder shall be in writing and
deemed given when personally delivered or deposited in the mail, postage prepaid and addressed to the
parties as follows:
[BUILDING AUTHORITY ADDRESS] [FIRE AUTHORITY ADDRESS]
__________________________________ __________________________________
__________________________________ __________________________________
__________________________________ __________________________________
__________________________________ __________________________________
Phone: ____________________________ Phone: ____________________________
Fax: _______________________________ Fax: _______________________________
Any notice so delivered personally shall be deemed to be received on the date of delivery, and any notice
mailed shall be deemed to be received five (5) days after the date on which it was mailed.
[BUILDING AUTHORITY ADDRESS] [FIRE AUTHORITY ADDRESS]
By: _______________________________ By: _______________________________
Date: ______________________________ Date: ______________________________
Exhibit A – Scope of Work
Part 3: PV Toolkit for Local Governments 57
This document has two sections. Neither section is all-inclusive as this document is simply a tool to aid the
inspection process.
SECTION 1 – Field Inspection Guide: The purpose of this section is to give the field inspector a
single-page reminder of the most important items in a field inspection.
SECTION 2- Comprehensive Reference: This reference details items that may be relevant in the field
inspection of rooftop PV systems that comply with the comprehensive or simplified versions of the
“Solar PV Standard Plan.” Not all items outlined in this section are relevant to each PV system. This
inspection reference details most of the issues that relate to the PV system during the inspection
process.
All California Electrical Code (CEC), California Residential Code (CRC), California Building Code (CBC)
and California Fire Code (CFC) references are to the 2013 versions unless otherwise noted.
TOOLKIT DOCUMENT #7
Inspection Guide for PV Systems in
One- and Two-Family Dwellings
(For Rooftop Photovoltaic Systems meeting the Standard Plan)
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California Solar Permitting Guidebook58
SECTION 1: Field Inspection Guide for Rooftop Photovoltaic (PV) Systems Standard Plan
Make sure all PV system AC/DC disconnects and circuit breakers are in the open position and verify the
following.
1. All work done in a neat and workmanlike manner (CEC 110.12).
2. PV module model number, quantity and location according to the approved plan.
3. Array mounting system and structural connections according to the approved plan.
4. Roof penetrations flashed/sealed according to the approved plan.
5. Array exposed conductors are properly secured, supported and routed to prevent physical damage.
6. Conduit installation according to CRC R331.3 and CEC 690.4(F).
7. Firefighter access according to approved plan.
8. Roof-mounted PV systems have the required fire classification (CBC 1505.9 or CRC R902.4).
9. Grounding/bonding of rack and modules according to the manufacturer’s installation instructions that are
approved and listed.
10. 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).
11. For grid-connected systems, inverter is marked “utility interactive.”
12. For ungrounded inverters, installation complies with CEC 690.35 requirements.
13. Conductors, cables and conduit types, sizes and markings according to the approved plan.
14. Overcurrent devices are the type and size according to the approved plan.
15. Disconnects according to the approved plan and properly located as required by the CEC.
16. Inverter output circuit breaker is located at opposite end of bus from utility supply at load center and/or
service panelboard (not required if the sum of the inverter and utility supply circuit breakers is less than or
equal to the panelboard bus rating).
17. PV system markings, labels and signs according to the approved plan.
18. Connection of the PV system to the grounding electrode system according to the approved plan.
19. Access and working space for operation and maintenance of PV equipment such as inverters,
disconnecting means and panelboards (not required for PV modules) (CEC 110.26).
Part 3: PV Toolkit for Local Governments 59
SECTION 2: Comprehensive Inspection Reference
GENERAL
1. Module manufacturer, make, model and number of modules match the approved plans. (CBC 107.4)
2. DC PV modules are listed to UL 1703. Ac modules are listed to UL 1703 and UL 1741. (CEC 110.3, 690.4
& CBC 1509.7.4 & CRC R908.1.5)
3. Modules are attached to the mounting structure according to the manufacturer’s instructions and the
approved plans. (CEC 110.3[B], CBC 107.4 & CRC R908.1.4)
4. Roof penetrations/attachments are properly flashed. (CBC Chapter 15 & 2012 CRC Chapter 9)
5. Rooftop systems are designed in accordance with the CBC. (CBC 1509.7 & CRC R908.1)
6. Roof access points, paths and clearances need to comply with the CFC. (CFC 605.11.3.1 - 605.11.3.3.3,
CRC R331.4.1 through R331.4.2.4)
7. PV installation shall comply with requirements of the standard plan.
8. PV system operating at 80 volts or greater shall be protected by a listed DC arc fault protection. (CEC
690.11)
9. All work done in a neat and workmanlike manner. (CEC 110.12)
ELECTRICAL REQUIREMENTS
PV Array Configuration
10. DC modules are properly marked and labeled. (CEC 110.3, 690.4[D] & 690.51)
11. AC modules are properly marked and labeled. (CEC 110.3, 690.4[D] & 690.52)
12. PV modules are in good condition (i.e., no broken glass or cells, no discoloration, frames not damaged,
etc.). (CEC 110.12[B])
13. Residential one and two family dwelling limited to maximum PV system voltage of 600 volts. (CEC 690.7)
Bonding and grounding
14. A complete grounding electrode system is installed. (CEC 690.47[A] & [B])
15. Modules are bonded and grounded in accordance with the manufacturer’s installation instructions, that
are listed and approved, using the supplied hardware or listed equipment specified in the instructions and
identified for the environment. (CEC 690.43 & 110.3[B])
16. Racking systems are bonded and grounded in accordance with the manufacturer’s installation instructions,
that are listed and approved, using the supplied hardware or listed equipment specified in the instructions
and identified for the environment. (CEC 690.43 & 110.3[B])
17. Properly sized equipment grounding conductor is routed with the circuit conductors. (CEC 690.45,
250.134[B] & 300.3[B])
18. AC and DC grounding electrode conductors are properly connected as required by code. Separate
electrodes, if used, are bonded together. (CEC 690.47, 250.50 & 250.58)
California Solar Permitting Guidebook60
19. Bonding fittings are used on concentric/eccentric knockouts with metal conduits for circuits over 250
volts. (CEC 250.97) (see also exceptions 1 through 4)
20. Bonding fittings are used for ferrous metal conduits enclosing grounding electrode conductors. (CEC
250.64[E])
PV Source/output Circuit Conductor Management
21. Cables are secured by staples, cable ties, straps, hangers or similar fittings at intervals that do not exceed
4.5 feet. (CEC 334.30 & 338.12[A][3])
22. Cables are secured within 12 inches of each box, cabinet, conduit body or other termination. (CEC 334.30
& 338.12[A][3])
23. Cable closely follows the surface of the building finish or of the running boards. (CEC 690.4[F] &
CFC 605.11.2 & CRC R331.3) NOTE: see Section 12 below for additional requirements on routing of
conductors for fire fighter safety concerns.
24. Exposed single conductors, where subject to physical damage, are protected. (CEC 230.50[B] & 300.5[D])
25. Exposed single conductors used for ungrounded systems are listed and identified as “PV wire.” (CEC
690.35[D][3]) For other conductor requirements for ungrounded systems, see CEC 690.35(D).
Conductors
26. Exposed single conductor wiring is a 90o C, wet rated and sunlight resistant type USE-2 or approved/listed
PV wire. (CEC 690.31[B] & 110.2) If the wiring is in a conduit, it is 90o C, wet rated type RHW-2, THWN-
2, or XHHW-2. (CEC 310.15)
27. Conductor insulation is rated at 90o C to allow for operation at 70o C+ near modules. (CEC 310.15)
28. Grounded conductor is identified white or gray. (CEC 200.6)
29. Open conductors are supported, secured and protected. (CEC 338.12[A][3] & 334.30)
30. Conductors are not in contact with the roof surface. (CEC 334.30)
31. DC conductors inside a building are in a metal raceway or MC metal-clad cable that complies with
250.118(10), or metal enclosures. (CEC 690.31[E])
32. DC wiring methods shall not be installed within 25cm (10”) of the roof decking or sheathing except where
directly below the roof surface covered by the PV modules and associated equipment. (CEC 690.31[E][1])
33. If more than one nominal voltage system conductor is installed in the raceway, permanent identification
and labeling is required. (CEC 200.6[D] & 210.5[C])
34. For underground conductor installations, the burial depth is appropriate and warning tape is in place.
(CEC 300.5[D][3] & Table 300.5)
35. Aluminum is not placed in direct contact with concrete. (CEC 250.120[B] & 110.11)
36. PV circuit and premises wiring is separated. (CEC 690.4[B])
37. PV system conductors shall be grouped and identified. (CEC 690.4[B])
Part 3: PV Toolkit for Local Governments 61
Overcurrent Protection
38. Overcurrent protection devices (OCPD) in the DC circuits are listed for DC operation. (CEC 110.3[A],
[B] & 690.9[D])
39. Overcurrent protection devices shall be provided per the approved plans. (CEC 690.9[A])
40. Combiner box is listed to UL 1741.
41. PV output OCPD is located at the opposite end of the bus from the feeder connection, unless otherwise
approved. (CEC 705.12[D][7])
Electrical Connections
42. Crimp terminals are listed and installed using a listed tool specified for use in crimping those specific
crimps. (CEC 110.3[B] & 110.14)
43. Pressure terminals are listed for the environment and tightened to manufacturer recommended torque
specifications. (CEC 110.11, 110.3[B] & 110.14)
44. Connectors are listed for the voltage of the system and have appropriate temperature and ampere ratings.
(CEC 110.3[B] & 110.14)
45. Twist-on wire connectors are listed for the environment (i.e., wet, damp, direct burial, etc.) and installed
per manufacturer’s instructions. (CEC 110.11, 110.3[B], 110.14 & 300.5[B])
46. Power distribution blocks are listed. (CEC 690.4 & 2011 NEC 314.28[E])
47. Terminals containing more than one conductor are listed for multiple conductors. (CEC 110.14[A] &
110.3[B])
48. Connectors and terminals used other than class B and C stranded conductors (fine stranded conductors)
are listed and identified for use with specific conductor class or classes.. (CEC 110.14[A] & 110.3[B])
49. Connectors that are readily accessible and operating at over 30 volts require a tool for opening. (CEC
690.33[C])
50. All connectors are fully engages, tight and secure. (CEC 110.3[B] & 110.12)
51. Wiring and connections of inverters, PV source circuits, etc., and all interconnections are performed by
qualified personnel. (CEC 690.4[E])
Disconnects
52. Disconnects used in DC circuits are listed for DC operation and located as allowed by the AHJ. (CEC
110.3)
53. Disconnects are installed for all current carrying conductors of the PV source. (CEC 690.13 - 690.14 &
690.35)
54. Disconnects are installed for the PV equipment. NOTE: For inverters and other equipment that are
energized from more than one source, the disconnecting means must be grouped and identified per AHJ’s
requirements. (CEC 690.15)
55. Disconnects and overcurrent protection are installed for all ungrounded conductors in ungrounded PV
power systems. (CEC 240.15 & 690.35)
56. Where connectors are used as disconnecting means, they shall be used in accordance with CEC 690.33.E
(CEC 690.33.E & 690.17)
California Solar Permitting Guidebook62
Inverters
57. Inverters are listed to UL 1741. (CEC 690.4[D]) NOTE: grid-tied system inverters need to be identified for
use in interactive power systems.
58. Point of connection is at a dedicated breaker or disconnect. (CEC 705.12[D][1])
59. Where a back-fed breaker is used as a utility interconnection means, the breaker is not marked “line and
load.” (CEC 110.3[B], 705.12[D][5])
60. Listed AC and DC disconnects and overcurrent protection are grouped and identified. (CEC 690.15)
61. No multiwire branch circuits are installed where single 120-volt inverters are connected to 120/240-volt
load centers. (CEC 690.10[C])
62. The barrier is reinstalled between the AC, DC wiring and communication wires. (CEC 110.3[B] & 110.27)
Signs and Labels
63. All interior and exterior DC conduit, enclosures, raceways, cable assemblies, junction boxes, combiner
boxes and disconnects are marked. (CFC 605.11.1, CEC 690.31[E][3], CEC 690.31[E][4], 690.17 & 690.53
& CRC R331.2)
64. The markings on the conduits, raceways and cable assemblies are 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. (CFC 605.11.1.4, CRC R331.2.4, CEC 690.31[E][3] & CEC 690.31[E][4])
65. Marking is placed adjacent to the main service disconnect in a location clearly visible from where the
disconnect is operated. (CFC 605.11.1.3 & CRC R331.2.3)
66. The markings say “WARNING: PHOTOVOLTAIC POWER SOURCE” and have 3/8-inch (9.5 mm)
minimum-sized white letters on a red background. The signs are made of reflective weather resistant
material. (CFC 605.11.1.1, 605.11.1.2& CRC R331.2.1 - R331.2.2 & CEC 690.31[E)][3] & 690.31[E][4])
67. Where PV circuits are embedded in built-up, laminate or membrane roofing materials in roof areas not
covered by PV modules and associated equipment, the location of circuits shall be clearly marked. (CEC
690.4[F])
68. Required labels shall be permanent and suitable for the environment. The following labels are required as
applicable.
Part 3: PV Toolkit for Local Governments 63
Table 1. Signage Requirements for PV systems
Code Section Location of Label Text
CEC 690.5(C)Utility-interactive inverter & battery
enclosure
WARNING: ELECTRIC SHOCK HAZARD
IF A GROUND FAULT IS INDICATED,
NORMALLY GROUNDED CONDUCTORS
MAY BE UNGROUNDED AND
ENERGIZED
CEC 690.35(F)All enclosures with ungrounded circuits
or devices which are energized and may
be exposed during service
WARNING: ELECTRIC SHOCK
HAZARD. THE DC CONDUCTORS
OF THIS PHOTOVOLTAIC SYSTEM
ARE UNGROUNDED AND MAY BE
ENERGIZED.
CEC 690.14(C)(1)On the main service when DC wiring
is run through the building and the DC
disconnect is located other than at the
main service
DC DISCONNECT IS LOCATED….
CEC 690.14(C)(2)On the AC and DC disconnects PHOTOVOLTAIC SYSTEM DISCONNECT
CEC 690.53 On the DC disconnects OPERATING CURRENT _________
OPERATING VOLTAGE __________
MAXIMUM SYSTEM VOLTAGE ___
SHORT CIRCUIT CURRENT ______
CEC 690.54 At interactive points of interconnection,
usually the main service
RATED AC OUTPUT CURRENT
______ AMPS
NORMAL OPERATING AC VOLTAGE
_______ VOLTS
CEC 690.56(B)/
690.14(D)(4), 705.10
2011 CEC 690.4(H)
At the electrical service and at the PV
inverter if not at the same location
A directory providing the location of
the service disconnecting means and
the photovoltaic system disconnecting
means
CEC 690.17 On the DC disconnect and on any
equipment that stays energized in the
off position from the PV supply
WARNING! ELECTRIC SHOCK HAZARD.
DO NOT TOUCH TERMINALS.
TERMINALS ON BOTH THE LINE AND
LOAD SIDES MAY BE ENERGIZED IN THE
OPEN POSITION.
CEC 705.12 (D)(7)Inverter output OCPD WARNING: INVERTER OUTPUT
CONNECTION DO NOT RELOCATE THIS
OVERCURRENT DEVICE.
CFC 605.11.1.4, CEC 690.31(E)(3),
690.31(E)(4), CRC R331.2.4
On conduit, raceways and enclosures,
mark every 10 feet, at turns, above/
below penetrations
WARNING: PHOTOVOLTAIC POWER
SOURCE.
Note: This label shall have a red
background with white lettering
California Solar Permitting Guidebook64
FIRE SAFETY REQUIREMENTS
1. Rooftop-mounted PV panels and modules have the proper fire classification rating. (CBC 1509.7.2 & CRC
R908.1.2)
2. Conduit, wiring systems and raceways for photovoltaic circuits are located as close as possible to the ridge,
hip or valley and from the hip or valley as directly as possible to an outside wall to reduce trip hazards and
maximize ventilation opportunities. (CFC 605.11.2 & CRC R331.3)
3. Conduit runs between sub arrays and to DC combiner boxes are installed in a manner that minimizes total
amount of conduit on the roof by taking the shortest path from the array to the DC combiner box. (CFC
605.11.2 & CRC R331.3)
4. DC Combiner Boxes are located so that conduit runs are minimized in the pathways between arrays. (CFC
605.11.2 & CRC 331.3)
5. DC wiring in enclosed spaces in buildings is installed in metallic conduit or raceways. Conduit runs along
the bottom of load bearing members. (CFC 605.11.2 & CEC 690.4[F] & CRC R331.3)
6. All roofs have an access point that does not place ground ladders over openings such as windows or doors,
are located at strong points of building construction, and in locations where the access point does not
conflict with overhead obstructions such as tree limbs, wires, or signs. (CFC 605.11.3.1 & CRC R331.3)
7. Roofs with slopes greater than 2:12 have solar panel layouts with access pathways that comply with
approved roof plan that meet the following criteria: (some exceptions apply, see diagrams in the California
Solar Permitting Guidebook)
A. Hip Roofs: Panels/modules are located so that there is a 3-foot wide clear access pathway from the
eave to the ridge on each roof slope where panels/modules are located. ( CFC 605.11.3.2.1 & CRC
R331.4.2.1)
B. Hips and Valleys: If panels/modules are placed on both sides of a hip or valley they are located no
closer than 18 inches to a hip or valley. If the panels are located on only one side of a hip or valley that
is of equal length, then the panels can be placed directly adjacent to the hip or valley. (CFC 605.11.3.2.3
& CRC R 331.4.2.3)
C. Single Ridges: Panels/modules are located so that there are two 3-foot wide access pathways from the
eave to the ridge on each roof slope where there are panels/modules installed. (CFC 605.11.3.2.2 &
CRC R331.4.2.2)
D. Ridges: Panels/modules are located no higher than 3 feet from the top of the ridge in order to allow for
fire department smoke ventilation operations. (CFC605.11.3.2.4 & CRC R331.4.2.4)
E. Access pathways are located at a structurally sound location capable of supporting the load of fire
fighters accessing the roof. (CFC 605.11.3.2.1 & CRC R331.4.2.1)
STRUCTURAL AND OTHER CODE REQUIREMENTS
List the structural requirements by the Authority Having Jurisdiction.
Part 4: Recommendations for Expedited Solar Thermal Installations 65
RECOMMENDATIONS FOR EXPEDITED SOLAR
THERMAL INSTALLATIONS
THERMAL TOOLKIT: STREAMLINED SOLAR THERMAL TEMPLATES
Under development for next edition (2015)
4Part
California Solar Permitting Guidebook66
RESOURCES AND INFORMATION
Understanding the Code
Code Requirements for Solar Photovoltaic (PV) Systems for One and Two-Family
Dwellings
Based on the 2013 California Building Code (CBC), the 2013 California Residential Code
(CRC) and the California Energy Code (CEC)
PURPOSE
The purpose of this information bulletin is to clarify requirements of the State Building Standards Codes
(Title 24) that pertain to solar PV installations on one- and two-family dwellings. This bulletin can serve as
a reference guide for permit applicants and enforcing agencies to clarify how state code requirements are
practically applied in the local jurisdiction. It is intended to minimize permitting uncertainty and differing
interpretation regarding specific code requirements for solar PV installations. This information bulletin
primarily clarifies requirements pertaining to the California Building Code and the California Residential
Code, since these codes in their current form require significant local interpretation. This information bulletin
does not address local regulations.
The implementation of uniform standards to achieve the timely and cost-effective installation is consistent
with the California Solar Rights Act that views solar installation as a matter of statewide concern and prohibits
local jurisdictions from adopting unreasonable barriers to the installation of solar energy systems (CA
Government Code Section 65850.5).
PART I: BUILDING AND RESIDENTIAL CODE REQUIREMENTS
1. Definitions
1.1 Solar photovoltaic system: The total components and subsystems that, in combination, convert solar
energy into electric energy suitable for connection to utilization load (CEC Article 100 and Article
690.2)
1.2 Module: A complete, environmentally protected unit consisting of solar cells, optics and other
components, exclusive of tracker, designed to generate DC power when exposed to sunlight (CEC
Article 690.2)
1.3 Panel: A collection of modules mechanically fastened together, wired and designed to provide a field-
installable unit (CEC Article 690.2)
1.4 Building integrated photovoltaics (BIPV): Photovoltaic cells, devices, modules or modular materials
that are integrated into the outer surface or structure of a building and serve as the outer protective
surface of the building (CEC Article 690.2)
1.5 Alternating-current (AC) module (alternating-current photovoltaic module): A complete,
environmentally protected unit consisting of solar cells, optics, inverter and other components,
exclusive of tracker, designed to generate AC power when exposed to sunlight (CEC Article 690.2
1.6 Photovoltaic modules/shingles: A roof covering composed of flat-plate photovoltaic modules
fabricated into shingles. (CRC Chapter 2, Section 202)
5Part
Part 5: Resources and Information 67
2. Solar Ready Requirements
The California Energy Code (Section 110.10) contains mandatory requirements for solar readiness in certain
newly constructed single-family and multifamily residences. Although these requirements apply to new
construction only, these requirements are briefly outlined for informational purposes.
2.1 Solar Zone: Newly constructed homes are required to have an area on the roof or overhang available
for future solar installations that meets certain requirements:
2.1.1 Minimum area: The solar zone must be a minimum of 250 square feet, subject to certain
exceptions outlined in the code (Section 110.10.b.1.[b]).
2.1.2 Orientation: All sections of the solar zone located on steep-sloped roofs (defined as a roof whose
pitch is greater than 2:12) shall be oriented between 110 degrees and 270 degrees of true north.
2.1.3 Shading: The solar zone must be free of obstructions and may not be shaded by certain
obstructions outside the zone (Section 110.10.b.3).
2.2 Documentation: Construction documentation must clearly show the dead and live load for the solar
zone. Collateral loads for future solar energy systems do not need to be shown on the construction
documents. (Section 110.10[b][4])
Construction documentation must also show pathways for electrical or plumbing interconnections.
This includes a location for inverters and metering equipment and a pathway for routing of conduit
from the solar zone to the point of interconnection with the electrical service. For single-family
residences, the point of interconnection will be the main service panel. (Section 110.10[c])
This information must also be provided to the occupant. (Section 110.10[d])
2.3 Main Electrical Service Panel: The main electrical service panel shall have a minimum bus bar rating
of 200 amps and a marked reserved space for future solar electric installation. (Section 110.10[e])
3. Structural Requirements
3.1 PV systems positively anchored to the building
3.1.1 Exemption from structural calculations: The building official may waive the requirement for
structural calculations for solar PV installations on top of existing roofs if the official can readily
determine that the additional weight of the new solar PV system on the roof does not affect the
structural integrity of the building. Some jurisdictions may choose to use the provided Structural
Criteria for Flush-Mounted PV and Thermal Systems as a prescriptive approach for when
structural calculations can be waived, however, that varies by the enforcing agency.
3.1.2 Structural calculations for non-prequalified systems: When structural calculations are required,
calculations shall demonstrate that the primary structure will support the additional vertical and
lateral loads from the panels and related equipment.
Note 1: See the Appendix for additional guidance on structural calculations.
3.1.2.1 Roof dead load: The weight of solar PV systems shall be considered as dead load in the
design of the structure (CBC Section 1606, CRC Section R301.4).
For installation of conventional (not BIPV) solar PV panels on existing roofs, roof
live load is not imposed where PV panels occur, provided the clear distance under
the panels to top of the roof is less than 42” and provided the roof design is adequate
for the concentrated loads from the solar PV panel support frames. See Structural
Engineers Association of California (SEAOC) Solar PV-3 Live Load document for
additional information.
California Solar Permitting Guidebook68
When the roof live load is allowed to be reduced, consideration should be given to the
possibility that a roof may have more than one layer of existing roofing. For pre-1960
wood-framed construction, structural calculations may be based on actual (field-
measured) lumber sizes (typically greater than modern lumber sizes), and Douglas fir
Grade 1 may be assumed unless field conditions indicate otherwise.
3.1.2.2 Roof live load: Roof live load is not considered in areas covered by roof-mounted
panels where there is less than 42” clear under the panels. Roof surfaces not covered
by solar PV panels shall be designed for the roof live load (CBC Section 1607, CRC
R301.6).
The building official may determine that live load need not be considered for solar PV
panels and associated supporting members that are built on grade. Such interpretation
is generally based on the assumption that the solar PV panels will not be stepped on or
used by anyone to support any live load
3.1.2.3 Wind design: Calculations shall demonstrate that the solar PV panels and associated
supporting members are designed to resist wind loads. For ballasted PV systems, see
Section 2.2 of this information bulletin (CBC Section 1609, CRC R301.2.1).
Photovoltaic modules/shingle packaging shall bear a label to indicate compliance
with the procedures in ASTM D 3161 and the required classification from CRC Table
R905.2.4.1(2) Classification of Asphalt Shingles Per ASTM D 3161 (CRC Section
R905.16.3).
For ballasted PV systems, see Code Requirements for Solar Photovoltaic (PV) Systems
– General, Section 2.2 of this information
3.1.2.4 Seismic design: Calculations shall demonstrate that the solar PV panels and associated
supporting members are designed to resist earthquake loads.
3.1.2.5 For wood construction, supports shall be attached with fasteners of sufficient length
and size to achieve minimum required embedment into solid wood taking into
consideration the plywood and multiple layers of roofing that may exist, unless
otherwise approved by the enforcing agency (CRC Section R301.1.3).
3.1.2.6 Snow load: When applicable, include snow loads and loads from snowdrift (CBC
Section 1608, CRC R301.2.3).
3.1.2.7 Requirements for load combinations: The applicable load combinations in CBC 1605
may be applied to all loading conditions, including evaluating the effects of dead load
to counteract wind uplift.
3.1.2.8 The Division of the State Architect (DSA) Interpretation of Regulations Article 16.8,
intended for public schools, provides useful code interpretation guidance to non-
DSA code officials regarding several types of solar systems, both ground- and roof-
mounted.
3.2 Structural strength of PV panels: The structural strength of solar PV panels is not addressed in the
code.
UL 1703, Third Edition, published March 15, 2002, requires that solar PV panels be tested to
withstand a superimposed load of 30 PSF. Therefore, all solar PV panels that are listed per UL 1703 are
considered to meet this requirement.
Part 5: Resources and Information 69
When used as a building component and depending on the load values that the solar PV panels
are subjected to, the enforcing agency may require a test report from an agency recognized by the
enforcing agency showing the strength of the solar PV panels.
3.3 Condition of existing roof: Solar PV systems shall not be installed on an existing roof that is
deteriorated to the point where it is not adequate as a base (this interpretation is based on CRC R907).
3.4 Premanufactured support systems: Premanufactured support systems must support the PV system
and allow the system to stay attached to the structure when exposed to wind, snow or seismic load.
Compliance of the PV support system with appropriate building codes is accomplished through
a design specified by a licensed engineer or architect or through research reports from approved
sources as addressed in CBC Section 1703.4.2. Solar support component manufacturers often provide
structural engineering design guidelines, worksheets, code compliance reports and Internet website
calculators. The manufacturer’s engineering guidelines are intended to ensure that the PV system
above the roof and its connection to the roof assembly are code compliant. Additional requirements
may be imposed by the enforcing agency (CRC Section R301.1.3).
4. Fire Safety Provisions
4.1 Fire/roof classification of photovoltaic (PV) panels
4.1.1 Solar PV panels installed on top of a building’s roof structure
4.1.1.1 Solar PV systems installed on top of a roof where the space between the solar
PV panels and the roof has no use and no potential use are generally considered
equipment. These solar PV panels/models shall comply with the minimum fire/roof
classification requirements or roof covering as required by the current CRC Section
R902.4
For installations in State Responsibility Areas (SRA) or High Fire Hazard Severity
Zones, additional provisions adopted by the local enforcing agency may be applicable.
Check with the enforcing agency for any additional requirements.
4.1.1.2 Solar PV panels used as roofing on an independent (stand-alone) structure: Solar PV
panels/modules that are designed to be on the roof and span to structural supports,
and have a use or occupancy underneath, shall comply with the minimum fire/roof
classification requirements for roof covering as required by CRC Section R902.4. An
example of this type of installation is a carport structure having solar PV panels as the
roof.
4.1.1.3 Solar PV panels installed as a part of a building’s roof structure: Solar PV panels
installed as integrated roofing material shall comply with the minimum fire/roof
classification requirements for roof covering as required by the current CRC Section
R902. An example of this type of installation is PV modules integrated into the roofing
shingles (BIPV systems).
4.1.2 Solar PV systems installed on grade: Solar PV panels that are part of a stand-alone, ground-
mounted solar PV panel structure, with no use and no potential use underneath are generally
considered equipment and therefore the fire/roof classification requirements would not apply. The
solar PV panels will require a clear, brush-free area of 10 feet around the installation (based on the
definition of a roof assembly in CRC Section R202 and R331.5).
4.2 Area, height and story limitations: Where there is a use between the solar PV panels and the roof/
grade underneath, adding such solar PV structures may constitute additional floor area, story and/
or height. Solar PV panels supported by framing that has sufficient uniformly distributed and
California Solar Permitting Guidebook70
unobstructed openings throughout the top of the array (horizontal plane) to allow heat and gases to
escape, as determined by the enforcing agency, are generally considered equipment.
4.3 Location from property line and adjacent buildings: Solar PV panels and associated framing, with
no use and no potential use between the panels and the grade underneath, are generally treated as
equipment. When not considered equipment, they may be considered a structure and shall be located
and protected based upon the code required fire separation distance to property lines and adjacent
buildings. (CRC Section R302.1)
4.4 Roof Access and Pathways: The installation of solar PV systems must allow for fire department
smoke ventilation operations. Roof access point, clear access pathways, solar PV systems spacing and
layout must comply with the requirements outlined in CRC Section R331.
4.5 Markings: The solar PV systems must be marked or labeled in accordance with CRC Section R331
and CEC Article 690. Markings are to be placed every 10 feet and in other areas as required.
4.6 Other fire safety requirements or guidelines: The installation of solar PV systems may be subject
to additional provisions adopted by the local enforcing agency. Check with the enforcing agency for
additional requirements.
5. Roof drainage: Roof-mounted solar PV systems shall not cause excessive sagging of the roof that results
in water ponding. They shall also not block or impede drainage flows to roof drains and scuppers. (CRC
Section R903.4; CPC Section 1101.11 also applies)
6. Roof penetrations: All roof penetrations shall be sealed using approved methods and products to
prevent water leakage. Such methods include but not limited to caulking, roof jacks and sheet metal
flashing. (CRC Section R903.2)
7. Skylights: Solar PV panels shall maintain a minimum clearance around the perimeter of skylights as not
to interfere with the function of the skylight, as determined by the enforcing agency
8. Plumbing vent, mechanical equipment and mechanical exhaust terminations: Solar PV
panels shall not obstruct or interfere with the function of plumbing vents or mechanical equipment. (CPC
Sections 901.1 & 906, CMC Section 304)
PART II: ELECTRICAL CODE REQUIREMENTS
1. Product listing (certification): The solar PV panel/module and other equipment used in the PV
system shall be listed/certified by a nationally recognized listing/certification agency in accordance with
the applicable standards.
2. Installation: The installation of the solar PV system must conform to the requirements of the California
Electrical Code (CEC).
3. Signage: Signage must conform to the requirements of the CEC. Signage requirements and location of
certain equipment for solar PV systems may be subject to additional provisions adopted by the enforcing
agency.
PART III: LOCAL ELECTRIC UTILITY REQUIREMENTS
Check with the local utility for any incentives, interconnection, operating and metering requirements.
Part 5: Resources and Information 71
Code Requirements for PV on Buildings other than One- and Two- Family Dwellings
Based on the 2013 California Building Code (CBC), California Residential Code (CRC)
and California Energy Code (CEC)
PURPOSE
The purpose of this information bulletin is to clarify requirements of the State Building Standards Codes (Title
24) that pertain to solar PV installations. This bulletin can serve as a reference guide for permit applicants and
enforcing agencies to clarify how state code requirements are practically applied in the local jurisdiction. It is
intended to minimize permitting uncertainty and differing interpretation regarding specific code requirements
for solar PV installations. This information bulletin primarily clarifies requirements pertaining to the
California Building Code and the California Residential Code, since these codes in their current form require
significant local interpretation. This information bulletin does not address local regulations.
The implementation of uniform standards to achieve the timely and cost-effective installation is consistent
with the California Solar Rights Act that views solar installation as a matter of statewide concern and prohibits
local jurisdictions from adopting unreasonable barriers to the installation of solar energy systems (CA
Government Code Section 65850.5).
PART I: BUILDING AND RESIDENTIAL CODE REQUIREMENTS
1. Definitions
1.1 Solar photovoltaic (PV) system: The total components and subsystems that, in combination, convert
solar energy into electric energy suitable for connection to utilization load (CEC Article 100 and
Article 690.2)
1.2 Module: A complete, environmentally protected unit consisting of solar cells, optics and other
components, exclusive of tracker, designed to generate DC power when exposed to sunlight (CEC
Article 690.2)
1.3 Panel: A collection of modules mechanically fastened together, wired and designed to provide a field-
installable unit (CEC Article 690.2)
Building integrated photovoltaics (BIPV): Photovoltaic cells, devices, modules or modular materials
that are integrated into the outer surface or structure of a building and serve as the outer protective
surface of the building (CEC Article 690.2).
1.4.1 Photovoltaic modules/shingles: A roof covering composed of flat-plate photovoltaic modules
fabricated in sheets that resemble three-tab composite shingles (CBC Chapter 2, Section 202).
1.5 Alternating-current (AC) module (alternating-current photovoltaic module): A complete,
environmentally protected unit consisting of solar cells, optics, inverter and other components,
exclusive of tracker, designed to generate AC power when exposed to sunlight (CEC Article 690.2).
1.6 Ballasted photovoltaic system: A roof-mounted system composed of solar photovoltaic panels and
supporting members that are unattached or partially attached to the roof and must rely on its weight,
aerodynamics and friction to counter the effect of wind and seismic forces (CBC Chapter 16, 1613.5.1
[1.2]).
2. Solar Ready Requirements
The California Energy Code (Section 110.10) contains mandatory requirements for solar readiness in certain
newly constructed single-family and multifamily residences. Although these requirements apply to new
construction only, they are briefly outlined here for informational purposes.
California Solar Permitting Guidebook72
2.1 Solar Zone: Subject to certain exceptions outlined in the code, newly constructed homes are required
to have an area designated for future solar installations on the roof or overhang of the building, the
roof or overhang of another structure located within 250 feet of the building or covered parking
installed with the building project. This area must meet certain requirements. The minimum solar
zone area must have the following.
2.1.1 Minimum area: The solar zone must be no less than 15 percent of the total roof area of the
building excluding any skylight area.
2.1.2 Orientation: All sections of the solar zone located on steep-sloped roofs (defined as a roof whose
pitch is greater than 2:12) shall be oriented between 110 degrees and 270 degrees of true north.
2.1.3 Shading: The solar zone must be free of obstructions and may not be shaded by certain
obstructions outside the zone (Section 110.10.b.2).
2.2 Documentation: Construction documentation must clearly show the dead and live load for the solar zone.
Collateral loads for future solar energy systems do not need to be shown on the construction documents.
Construction documentation must also show pathways for electrical or plumbing interconnections.
This includes a location for inverters and metering equipment and a pathway for routing of conduit
from the solar zone to the point of interconnection with the electrical service. For single-family
residences, the point of interconnection will be the main service panel.
This information must also be provided to the occupant.
2.3 Main Electrical Service Panel
The main electrical service panel shall have a minimum bus bar rating of 200 amps and a marked
reserved space for future solar electric installation.
3. Structural Requirements
3.1 PV systems positively anchored to the building
3.1.1 Exemption from structural calculations: The building official may waive the requirement for
structural calculations for solar PV installations on top of existing roofs if the official can readily
determine that the additional weight of the new solar PV system on the roof does not affect the
structural integrity of the building. Some jurisdictions may have a prescriptive approach for when
structural calculations can be waived, however, that varies by the enforcing agency.
To help streamline and simplify the permitting process for roof-mounted solar PV systems, it
is highly recommended that local jurisdictions develop a prescriptive approach to meeting the
structural requirements so that structural calculations are not always required. Some parameters
to consider under such prescriptive approach include the following.
• Maximum distributed weight of the solar PV system in PSF
• Maximum perpendicular distance between the solar PV system and the roof below
• Maximum concentrated load imposed by the PV panel support onto the building’s roof
• Minimum size and spacing of rafters or joists for portion of the roof that is supporting the
solar PV system
• Maximum span of rafters or joists for portion of the roof that is supporting the solar PV system
• Anchoring requirements such as type of fasteners, minimum fastener size, minimum
embedment and minimum number of attachment points
• Any limitation on the type of building construction
Part 5: Resources and Information 73
3.1.2 Structural calculations: When structural calculations are required, calculations shall demonstrate
that the primary structure will support the additional vertical and lateral loads from the panels
and related equipment.
Note 1: See the appendix to this document for additional guidance on structural calculations.
3.1.2.1 Roof dead load: The weight of solar PV systems shall be considered as dead load in the
design of the structure (CBC Section 1606, CRC Section R301.4).
For installation of conventional (not BIPV) solar PV panels on existing roofs, roof
live load is not imposed where PV panels occur, provided the clear distance under
the panels to top of the roof is less than 42” and provided the roof design is adequate
for the concentrated loads from the solar PV panel support frames. See Structural
Engineers Association of California (SEAOC) Solar PV-3 Live Load document for
additional information.
When the roof live load is allowed to be reduced, consideration should be given to the
possibility that a roof may have more than one layer of existing. For pre-1960 wood-
framed construction, structural calculations may be based on actual (field-measured)
lumber sizes (typically greater than modern lumber sizes) and Douglas fir Grade 1
may be assumed unless field conditions indicate otherwise.
Section 3403.3 of the CBC states, in part, that “Any existing gravity load-carrying
structural element for which an addition and its related alterations cause an increase
in design gravity load of more than 5 percent shall be strengthened, supplemented,
replaced or otherwise altered as needed to carry the increased load required by this
code for new structures.”
3.1.2.2 Roof live load: Roof live load is not considered in areas covered by roof-mounted
panels where there is less than 42” clear under the panels. Roof surfaces not covered
by solar PV panels shall be designed for the roof live load (CBC Section 1607, CRC
R301.6).
The building official may determine that live load need not be considered for solar PV
panels and associated supporting members that are built on grade. Such interpretation
is generally based on the assumption that the solar PV panels will not be stepped on or
used by anyone to support any live load
3.1.2.3 Wind design: Calculations shall demonstrate that the solar PV panels and associated
supporting members are designed to resist wind loads. For ballasted PV systems, see
Section 2.2 of this information bulletin (CBC Section 1609, CRC R301.2.1).
Photovoltaic modules/shingle packaging shall bear a label to indicate compliance
with the procedures in ASTM D 3161 and the required classification from
CBC Table 1507.2.7.1(2) Classification of Asphalt Shingles Per ASTM D 3161
(CBC Section 1507.2.7.1[2]).
The Structural Engineering Association of California has released a white paper
titled “Wind Loads on Low-Profile Solar Photovoltaic Systems on Flat Roofs.” This
document is available at http://files.engineering.com/download.aspx?folder=7ae26414-
8066-4d06-b001-198e5aaf6d88&file=2012-08_SEAOC_Solar_PV_wind_document_
Final.pdf.
3.1.2.4 Seismic design: Calculations shall demonstrate that the solar PV panels and associated
supporting members are designed to resist earthquake loads. For ballasted PV systems,
see Section 2.2 of this information bulletin (CBC Section 1613, CRC 301.2.2).
California Solar Permitting Guidebook74
Note that Section 3404.4 of the CBC states, in part, that “Any existing lateral load-
carrying structural element whose demand-capacity ratios with alteration considered
is no more than 5 percent greater than its demand-capacity ratio with the alteration
ignored shall be permitted to remain unaltered. . . .”
3.1.2.5 For wood construction, supports shall be attached with fasteners of sufficient length
and size to achieve minimum required embedment into solid wood taking into
consideration the plywood and multiple layers of roofing that may exist, unless
otherwise approved by the enforcing agency (ASCE/SEI 7 Section 13.4, CRC Section
R301.1.3).
3.1.2.6 Snow load: When applicable, include snow loads and loads from snowdrift (CBC
Section 1608, CRC R301.2.3).
3.1.2.7 Requirements for load combinations: The applicable load combinations in CBC 1605
shall be applied to all loading conditions, including evaluating the effects of dead load
to counteract wind uplift for ballasted and anchored systems (CBC Section 1605, CRC
Section R301.1.3).
3.1.2.8 Alterations, additions and repairs: Sections 3403, 3404, and 3405 of the CBC shall
apply to additions, alterations and repairs associated with PV systems. Roof structural
components, their connections, additions, alterations and repairs shall be designed to
support the loads from the PV panel support frames
3.1.2.9 The Division of the State Architect (DSA) Interpretation of Regulations Article 16.8,
intended for public schools, provides useful code interpretation guidance to non-DSA
code officials regarding several types of solar systems, both ground- and roof-mounted.
3.2 Ballasted PV system: PV panels in a ballasted system are typically not attached to the roof and rely
on their weight, aerodynamics and friction to counter the effect of wind and seismic forces. In some
cases, ballasted systems have few attachment points to supplement the friction forces. Ballasted
systems have low ratios of height-to-base width or length, which makes them inherently stable against
overturning.
Section 13.4 of ASCE/SEI 7-10 requires that nonstructural components and their supports be attached
(or anchored) to the structure. Ballasted solar PV systems are not addressed in the ASCE/SEI 7 and
not part of the 2010 CBC.
During the 2012 Triennial Code Adoption Cycle, the Department of Housing and Community
Development and the Building Standards Commission proposed an amendment in CBC Section 1613.5,
which provides a definition for ballasted photovoltaic systems and allows local governments to approve
such systems if they are inclined to accept the weight and friction methodology. This amendment was
developed by the Structural Engineers Association of California – Solar Photovoltaic Systems Committee
and was based on recently approved Item S72-12 at the ICC Code Development Hearing.
This new language, as written, provides building officials with additional criteria under which a
ballasted solar system can be permitted.
Note 1: Electrical connections and wiring in a ballasted system should be designed to accommodate
movements within the system.
Note 2: The Structural Engineering Association of California is in the process of developing a
white paper, titled “Structural Seismic Requirements and Commentary for Rooftop Solar
Photovoltaic Systems,” addressing the seismic design of ballasted systems. Once available, a
link to the white paper will be included in this document.
Part 5: Resources and Information 75
3.3 Structural strength of PV panels: The structural strength of solar PV panels is not addressed in the code.
UL 1703, Third Edition, published March 15, 2002, requires that solar PV panels be tested to
withstand a superimposed load of 30 PSF. Therefore, all solar PV panels that are listed per UL 1703 are
considered to meet this requirement. When used as a building component and depending on the load
values that the solar PV panels are subjected to, the enforcing agency may require a test report from an
agency recognized by the enforcing agency showing the strength of the solar PV panels.
3.4 Condition of existing roof: Solar PV systems shall not be installed on an existing roof that is
deteriorated to the point where it is not adequate as a base. (This interpretation is based on CBC
Section 1510 and CRC R907.)
3.5 Premanufactured support systems: Premanufactured support systems must support the PV system
and allow the system to stay attached to the structure when exposed to wind, snow or seismic loads.
Compliance of the PV support system with appropriate building codes is accomplished through a
design specified by a licensed engineer or architect or through research reports from approved sources
as defined in CBC Section 1703.4.2. Solar support component manufacturers often provide structural
engineering design guidelines, worksheets, code compliance reports and Internet website calculators.
The manufacturer’s engineering guidelines are intended to ensure that the solar array above the roof
and its connection to the roof are code compliant. Additional requirements may be imposed by the
enforcing agency (CRC Section R301.1.3, CBC Section 1703.4.2).
4. Fire Safety Provisions
4.1 Fire/roof classification of photovoltaic (PV) panels
4.1.1 Solar PV panels installed on top of a building’s roof structure
4.1.1.1 Solar PV systems installed on top of a roof where the space between the solar PV
panels and the roof has no use and no potential use are generally considered to be
equipment. These solar PV panels/modules shall comply with the minimum fire/roof
classification requirements for roof covers as required by CBC Section 1505.
For installations in State Responsibility Areas (SRA) or High Fire Hazard Severity
Zones, additional provisions adopted by the local enforcing agency may be applicable.
Check with the enforcing agency for any additional requirements.
4.1.1.2 Solar PV panels used as roofing on an independent (stand-alone) structure: Solar PV
panels/modules that are designed to be on the roof and span to structural supports,
and have a use or occupancy underneath, shall comply with the minimum fire/roof
classification requirements for roof covering as required by CRC Section R902. An
example of this type of installation is a carport structure having solar PV panels as the
roof.
4.1.1.3 Solar PV panels installed as a part of a building’s roof structure: Solar PV panels
installed as integrated roofing material shall comply with the minimum fire/roof
classification requirements for roof covering as required by the current CRC Section
R902. An example of this type of installation is PV modules integrated into the roofing
shingles (BIPV systems).
4.1.2 Solar PV systems installed on grade: Solar PV panels that are part of a stand-alone, ground-
mounted solar PV panel structures, with no use and no potential use underneath are generally
considered equipment and therefore the fire/roof classification requirements would not apply. The
solar PV panels will require a clear, brush free area of 10 feet around the installation. (Based on
the definition of a roof assembly in CRC Section R202/CBC Section 1502.)
California Solar Permitting Guidebook76
4.2 Area, height, and story limitations: Where there is a use between the solar PV panels and the
roof/ grade underneath, adding such solar PV structures may constitute additional floor area, story
and/or height. Solar PV panels supported by framing that has sufficient uniformly distributed and
unobstructed openings throughout the top of the array (horizontal plane) to allow heat and gases
to escape, as determined by the enforcing agency, are generally considered equipment. Provisions
relating to solar PV height and area requirements are contained in CBC Section 503 and Table 503.
4.3 Location from property line and adjacent buildings: Solar PV panels and associated framing, with
no use and no potential use between the panels and the grade underneath, are generally treated as
equipment. When not considered equipment, they may be considered a structure and shall be located
and protected based upon the code required fire separation distance to property lines and adjacent
buildings (CRC Section R302.1, CBC Section 602).
4.4 Fire proofing of structural support: Depending on the type of building, support structures of solar
PV systems that have a use or have potential for use underneath (such as carports) may be required to
be fire proofed in accordance with CBC Section 602.
4.4.1 The following installations are generally considered equipment and are not subject to this
requirement provided that the structural members are noncombustible.
Stand-alone PV panel structures with no use and no potential use underneath (based on
definition of a roof assembly in CBC Section 202).
Solar PV panels supported by framing that has sufficient uniformly distributed and unobstructed
openings throughout the top of the array (horizontal plane) to allow heat and gases to escape, as
determined by the enforcing agency (based on definition of a roof assembly in CBC Section 202).
4.4.2 Alternate designs can be considered when approved by the enforcing agency as an alternative
material, design or method of construction pursuant to CBC Sections 1.2.2, 1.8.7, or 1.11.2.4 as
applicable.
4.5 Rooftop structures: Unenclosed rooftop structures supporting solar PV systems with no use
underneath are generally not subject to CBC Section 1509.2.
4.6 Fire sprinklers: In buildings that are required to be provided with fire sprinklers, the CBC requires
that all parts of the building have sprinkler coverage except where an exemption is specifically
required. See amendments to NFPA section 8.15.7.6 in Chapter 35 of the CBC.
4.6.1 Solar photovoltaic (PV) panels supported by framing that have sufficient uniformly distributed
and unobstructed openings throughout the top of the array (horizontal plane) to allow heat
and gases to escape, as determined by the enforcing agency, are generally not subject to this
requirement (CBC Section 903.3.3).
4.6.2 Solar PV panels placed above the roof, with no use and no potential use between the panels and
the roof, are generally not subject to this requirement (based on definition of a roof assembly in
CBC Section 1502 and CRC Section R202).
4.6.3 Existing exemptions in the code may be used for a solar PV installation if it meets the intent of the
exemption. This will be subject to approval by the enforcing agency.
4.7 Roof Access and Pathways: The installation of solar PV systems must allow for fire department
smoke ventilation operations. Roof access point, clear access pathways, solar PV systems spacing and
layout must comply with the recruitments outlined in CRC Section R331
4.8 Markings: The solar PV systems must be marked or labeled in accordance with CRC Section R331
and CEC Article 690. Markings are to be placed every 10 feet and in other areas as required.
Part 5: Resources and Information 77
4.9 Other fire safety requirements or guidelines: The installation of solar PV systems may be subject
to additional provisions adopted by the local enforcing agency. Check with the enforcing agency for
additional requirements.
5. Roof drainage: Roof-mounted solar PV systems shall not cause excessive sagging of the roof that
results in water ponding. They shall also not block or impede drainage flows to roof drains and scuppers.
See CBC Section 1503.4 and CRC Section R903.4. CPC Section 1101.11 also applies.
6. Roof penetrations: All roof penetrations shall be sealed using approved methods and products to
prevent water leakage. Such methods include but not limited to caulking, roof jacks and sheet metal
flashing (CBC Section 1503.2, CRC Section R903.2).
7. Skylights: Solar PV panels shall maintain a minimum clearance around the perimeter of skylights as not
to interfere with the function of the skylight, as determined by the enforcing agency.
8. Plumbing vent, mechanical equipment and mechanical exhaust terminations: Solar
PV panels shall not obstruct or interfere with the function of plumbing vents or mechanical equipment
(CPC Sections 901.1 & 906, CMC Section 304).
9. Guard rails: When required by the enforcing agency, guard rails may apply to solar PV systems (CBC
Section 1013.6).
10. Disabled access requirements
10.1 Nonresidential, hotel, motel buildings, facilities or structures (See CBC Chapter 11B)
10.1.1 Scope: Accessibility to solar PV support structures that create a use or occupancy shall be
provided for all occupancy classifications in accordance with Chapter 11B.
10.1.2 General: When alterations, structural repairs or additions are made to existing buildings or
facilities for the purpose of installing a solar PV system, they shall comply with Chapter 11B.
Note: New solar PV systems that do not create or expand a use or occupancy and consist only of
installation of the solar PV system and related electrical work that does not affect disabled access
requirements for existing buildings regulated by Chapter 11B are not considered alterations for
the purpose of accessibility and should not be subject to accessibility upgrades.
10.2 Residential buildings, facilities or structures
10.2.1 Scope: New solar PV systems serving covered multifamily dwellings that create a use or
occupancy shall comply with the provisions of Chapter 11A.
10.2.2 Existing buildings: The building standards contained in Chapter 11A do not apply to the
installation of solar PV systems serving privately funded multifamily dwellings constructed for
first occupancy prior to March 13, 1991.
10.3 Parking: Required accessible parking spaces shall be provided and maintained in accordance with the
applicable provisions of Chapter 11A, Sections 1109A and Chapter 11B.
Note: Alterations: Where parking lots, parking structures or parking facilities are re-striped or
otherwise altered to accommodate solar PV systems, required accessible parking spaces shall be
maintained or shall be provided in accordance with the applicable provisions of Section 1109A and
Chapter 11B.
California Solar Permitting Guidebook78
PART II: ELECTRICAL CODE REQUIREMENTS
1. Product listing (certification): The solar PV panel/module and other equipment used in the PV
system shall be listed/certified by a nationally recognized listing/certification agency in accordance with the
applicable standards.
2. Installation: The installation of the solar PV system must conform to the requirements of the California
Electrical Code (CEC).
3. Signage: Signage must conform to the requirements of the (CEC). Signage requirements and location of
certain equipment for solar PV systems may be subject to additional provisions adopted by the enforcing
agency.
PART III: LOCAL ELECTRIC UTILITY REQUIREMENTS
Check with the local utility for any incentives, interconnection, operating and metering requirements.
Part 5: Resources and Information 79
GLOSSARY
AHJ: Acronym that stands for authority having jurisdiction. AHJ is often used to describe the designated
department or agency that enforces certain laws or regulations. It is often used interchangeably with the term
enforcing agency.
BIPV: Acronym that stands for building integrated photovoltaics, which is a form of photovoltaic solar energy
technology that is integrated into the building envelope to become a part of the roof, skylight or facade.
California Building Standards Commission: State entity that administers California’s building codes,
including the adoption, approval and publication. They follow a triennial code adoption cycle in which state
agencies submit their proposals for code changes.
California Department of Housing and Community Development (HCD): State department
responsible for preserving and expanding safe and affordable housing opportunities. HCD develops the
building standards that govern construction and maintenance on all forms of housing and ensures that the
standards are properly enforced, identifies California’s housing needs and develops policies to meet those
needs.
California State Fire Marshal: State office that supports CAL FIRE by focusing on fire prevention
through fire prevention engineering, training, education and enforcement.
Contractor: A contractor licensed by the State of California performing work within the scope of their
license.
Dead load: The weight of materials of construction incorporated into the building, including but not
limited to walls, floors, roofs, ceilings, stairways, built-in partitions, finishes, cladding and other similarly
incorporated architectural and structural items and the weight of fixed service equipment, such as cranes,
plumbing stacks and risers; electrical feeders; heating, ventilating and air-conditioning systems; and automatic
sprinkler systems.
Enforcement: (As defined in Title 24) A diligent effort to secure compliance, including review of plans and
permit applications, response to complaints, citation of violations and other legal process. Except as otherwise
provided in this part, “enforcement” may, but need not, include inspections of existing buildings on which no
complaint or permit application has been filed and effort to secure compliance as to these existing buildings.
Enforcing agency: The designated department or agency that enforces certain laws or regulations, as
specified by statute or regulation. In regard to solar PV installations, this entity is can also be referred to as
the “permitting agency,” since it is often the entity that issues a permit to allow for solar installations to be
constructed.
General plan: A document adopted by a city or county to create a long-term vision to guide the
jurisdictions future growth and land use. It includes a statement of development policies and implementing
actions to achieve its development objectives.
Live load: Those loads produced by the use and occupancy of the building or other structure and do not
include construction or environmental loads such as wind load, snow load, rain load, earthquake load, flood
load or dead load.
Photovoltaic: A method of generating electrical power by converting solar radiation (sunlight) into direct
current electricity using semiconductors.
California Solar Permitting Guidebook80
Qualified person: One who has the required state license and has proper skills and knowledge related to
the construction and operation of the electrical equipment and installations and has received safety training to
recognize and avoid the hazards involved.
Solar photovoltaic system: The total components and subsystems that, in combination, convert solar
energy into electric energy suitable for connection to utilization load.
Title 24: The section of the California Code of Regulations that governs the design and construction of all
buildings and associated facilities and equipment in California.
Part 5: Resources and Information 81
ADDITIONAL RESOURCES
Alternative Energy Equipment and Systems Marking and Application Guide
Underwriters Laboratories (UL) publishes the Alternative Energy Equipment and Systems Marking and
Application Guide. The guide provides application and UL product category information for PV systems,
thermal solar systems, fuel cells and hydrogen generators, engine generators, microturbines and wind turbine
generating systems. This guide is available online and can be found in Appendix A of the most recent UL
White Book.
California Solar Initiative Incentives
Information about state incentives offered for solar installations. Most incentives allocated for PV installations
have been exhausted, but incentives remain for new construction homes and solar thermal installations.
California Solar Energy Industries Association (CALSEIA)
CALSEIA provides a ready-made forum for public agencies to communicate with contractors and/or
seek feedback on changes to local permitting requirements or processes. Local chapters of CALSEIA exist
throughout the state.
Center for Sustainable Energy (CSE)
CSE provides implementation expertise and training to public agencies on solar permitting. CSE is the
statewide awardee of the Department of Energy’s Rooftop Solar Challenge, a component of the SunShot
Initiative. Template permitting documents and AB 2188 Implementation Guide are available online.
Energy Aware Planning Guide
Developed by the California Energy Commission, the Energy Aware Planning Guide is a comprehensive
resource for local governments seeking to reduce energy use, improve energy efficiency and increase adoption
of renewable energy across all sectors. The guide presents a menu of strategies and best management practices
to help local governments improve energy efficiency, reduce energy consumption through transportation and
land use and enhance renewable sources of energy.
Energy Aware Facility Siting and Permitting Guide
Developed by the California Energy Commission, the Energy Aware Facility Siting and Permitting Guide
assists local governments with developing general plan energy and transmission elements and provides
guidance on utility-scale electricity generation and transmission planning and permitting. The guide discusses
the increasing role of local governments in energy planning and permitting, describes the energy regulations
and policies (both federal and state) and planning processes that define future electricity generation and
transmission needs, and identifies opportunities for local government involvement in electricity infrastructure
planning and permitting.
Expedited Permit Process for PV System
Recommendations developed for the Solar American Board for Codes and Standards (Solar ABCs) by Bill
Brooks, P.E., Brooks Engineering. This document outlines a standardized review process for small-scale PV
systems.
Incentive and Interconnection Information
Following are weblinks to information on major utilities’ interconnection rules and procedures.
Los Angeles Department of Water and Power (LADWP)
California Solar Permitting Guidebook82
Pacific Gas and Electric (PG&E)
• Standard Net Energy Metering (includes links to Interconnection forms)
Sacramento Municipal Utility District (SMUD)
San Diego Gas and Electric (SDG&E)
Southern California Edison (SCE)
• Net Metering FAQs
• Net Energy Metering Interconnection Handbook
Sharing Success — Emerging Approaches to Efficient Rooftop Solar Permitting
Published by the Interstate Renewable Energy Council (IREC) in May 2012, this report outlines innovative
strategies being implemented across the U.S. to help increase the efficiency of permitting procedures for
rooftop solar systems.
Solar America Board for Codes and Standards (Solar ABCs)
Solar ABCs is a collaborative effort funded by the Department of Energy. This entity publishes several helpful
reports and recommendations, including a permit streamlining guideline.
Solar Energy Facilities Permit Streamlining Guide
A guide produced by the California County Planning Directors Association (CCPDA) to help counties
facilitate development of solar energy facilities. The guide describes the laws and regulations applying to solar
energy facilities, points to consider regarding solar energy development and lists current procurement and
incentive programs for renewable energy. The guide also provides a model ordinance regarding solar energy
facilities and further outlines policy options and guidance for counties regarding solar energy.
Solar Instructor Training Network
The Solar Instructor Training Network (SITN) promotes high-quality training in the installation of solar
technologies. Nine regional resource and training providers support the professional development of trainers
and instructors of solar PV and solar heating and cooling technologies across the country. The Interstate
Renewable Energy Council (IREC) became the national administrator of the Solar Instructor Training
Network in 2010. IREC also provides several guides and checklists on permitting best practices.
Structural Technical Appendix for Residential Rooftop Solar Installations
A detailed description of the structural engineering principles and assumptions behind Toolkit Document
5, Structural Criteria for Residential Rooftop Solar Energy Installations. This Appendix delineates how the
document conforms to the California Residential Code and California Building Code and also discusses
options that jurisdictions may want to consider in implementing Toolkit Document 5. Additionally, the
Technical Appendix offers guidance to address some nonconforming items, such as when an anchor layout is
not based on a solar support component manufacturer’s guidelines or when a dwelling is located within 200
yards of the ocean (Wind Exposure D).
California Solar Rights Act: A Review of the Statutes and Relevant Cases
The Energy Policy Initiatives Center at the University of San Diego School of Law has produced this detailed
analysis of the California Solar Rights Act. This review details the evolution of the act since its passage in the
late 1970s. A series of court cases, detailed in this document, have shaped how the act is applied and practiced
throughout the state.
Governor’s Office of Planning and Research
Office of Governor Edmund G. Brown Jr.
Assembly Bill No. 2188
CHAPTER 521
An act to amend Section 714 of the Civil Code, and to amend Section 65850.5 of the Government Code, relating to solar energy.
[ Approved by Governor September 21, 2014. Filed with Secretary of
State September 21, 2014. ]
LEGISLATIVE COUNSEL'S DIGEST
AB 2188, Muratsuchi. Solar energy: permits.
(1) Existing law provides that it is the policy of the state to promote and encourage the use of solar energy systems, as defined,
and to limit obstacles to their use. Existing law states that the implementation of consistent statewide standards to achieve timely
and cost-effective installation of solar energy systems is not a municipal affair, but is instead a matter of statewide concern.
Existing law requires a city or county to administratively approve applications to install solar energy systems through the
issuance of a building permit or similar nondiscretionary permit. Existing law requires a solar energy system for heating water to
be certified by the Solar Rating Certification Corporation or another nationally recognized certification agency.
This bill would specify that these provisions address a statewide concern. The bill would additionally require a city, county, or
city and county to adopt, on or before September 30, 2015, in consultation with specified public entities an ordinance that creates
an expedited, streamlined permitting process for small residential rooftop solar energy systems, as specified. The bill would
additionally require a city, county, or city and county to inspect a small residential rooftop solar energy system eligible for
expedited review in a timely manner, as specified. The bill would prohibit a city, county, or city and county from conditioning
the approval of any solar energy system permit on approval of that system by an association that manages a common interest
development. The bill would require a solar energy system for heating water in single family residences and solar collectors for
heating water in commercial or swimming pool applications to be certified by an accredited listing agency, as defined.
Because the bill would impose new duties upon local governments and local agencies, it would impose a state-mandated local
program.
(2) Existing law prohibits any covenant, restriction, or condition contained in any deed, contract, security instrument, or other
instrument affecting the transfer or sale of, or any interest in, real property, and any provision of a governing document from
effectively prohibiting or restricting the installation or use of a solar energy system. Existing law exempts from that prohibition
provisions that impose reasonable restrictions on a solar energy system that do not significantly increase the cost of the system or
significantly decrease its efficiency or specified performance. Existing law defines the term “significantly,” for these purposes,
with regard to solar domestic water heating systems or solar swimming pool heating systems that comply with state and federal
law, to mean an amount exceeding 20% of the cost of the system or decreasing the efficiency of the solar energy system by an
amount exceeding 20%, and with regard to photovoltaic systems that comply with state and federal law, an amount not to exceed
$2,000 over the system cost or a decrease in system efficiency of an amount exceeding 20%, as specified. Existing law requires a
solar energy system for heating water subject to the provisions described above to be certified by the Solar Rating Certification
Corporation or another nationally recognized certification agency.
This bill would instead define the term “significantly,” for these purposes, with regard to solar domestic water heating systems or
solar swimming pool heating systems that comply with state and federal law, to mean an amount exceeding 10% of the cost of
the system, not to exceed $1,000, or decreasing the efficiency of the solar energy system by an amount exceeding 10%, and with
regard to photovoltaic systems that comply with state and federal law, an amount not to exceed $1,000 over the system cost or a
decrease in system efficiency of an amount exceeding 10%, as specified. The bill would require a solar energy system for heating
water in single family residences and solar collectors for heating water in commercial or swimming pool applications subject to
the provisions described above to be certified by an accredited listing agency, as defined.
(3) Existing law requires an application for approval for the installation or use of a solar energy system to be processed and
approved by the appropriate approving entity in the same manner as an application for approval of an architectural modification
to the property and prohibits the approver from willfully avoiding or delaying approval. Existing law requires the approving
entity to notify the applicant in writing within 60 days of receipt of the application if the application is denied, as specified.
The bill would instead require the approving entity to notify the applicant in writing within 45 days of receipt of the application if
the application is denied, as specified.
The California Constitution requires the state to reimburse local agencies and school districts for certain costs mandated by the
state. Statutory provisions establish procedures for making that reimbursement.
This bill would provide that no reimbursement is required by this act for a specified reason.
DIGEST KEY
Vote: MAJORITY Appropriation: NO Fiscal Committee: YES Local Program: YES
BILL TEXT
THE PEOPLE OF THE STATE OF CALIFORNIA DO ENACT AS FOLLOWS:
SECTION 1.
The Legislature finds and declares all of the following:
(a) In recent years, the state has both encouraged the development of innovative distributed generation technology and prioritize d
the widespread adoption of solar power as a renewable energy resource through programs such as the California Solar Initiative.
(b) Rooftop solar energy is a leading renewable energy technology that will help this state reach its energy and environmental
goals.
(c) To reach the state’s Million Solar Roofs goal, hundreds of thousands of additional rooftop solar energy systems will need to
be deployed in the coming years.
(d) Various studies, including one by the Lawrence Berkeley National Laboratory, show that, despite the 1978 California Solar
Rights Act, declaring that the “implementation of consistent statewide standards to achieve the timely and cost-effective
installation of solar energy systems is not a municipal affair ... but is instead a matter of statewide concern,” the permitt ing
process governing the installation of rooftop solar energy systems varies widely across jurisdictions and, contrary to the intent of
the law, is both an “obstacle” to the state’s clean energy and greenhouse reduction goals and a “burdensome cost” to
homeowners, businesses, schools, and public agencies.
(e) The United States Department of Energy, through its SunShot Initiative, has distributed millions of dollars in grants to loca l
and state governments, including California jurisdictions, and nonprofit organizations to reduce th e costs of distributed solar
through streamlined and standardized permitting.
(f) A modernized and standardized permitting process for installations of small -scale solar distributed generation technology on
residential rooftops will increase the deployment of solar distributed generation, help to expand access to lower income
households, provide solar customers greater installation ease, improve the state’s ability to reach its clean energy goals, and
generate much needed jobs in the state, all while maintaining safety standards.
SEC. 2.
Section 714 of the Civil Code is amended to read:
714.
(a) Any covenant, restriction, or condition contained in any deed, contract, security instrument, or other instrument affecting t he
transfer or sale of, or any interest in, real property, and any provision of a governing document, as defined in Section 4150 or
6552, that effectively prohibits or restricts the installation or use of a solar energy system is void and unenforceable.
(b) This section does not apply to provisions that impose reasonable restrictions on solar energy systems. However, it is the
policy of the state to promote and encourage the use of solar energy systems and to remove obstacles thereto. Accordingly,
reasonable restrictions on a solar energy system are those restrictions that do not significantly increase the cost of the system or
significantly decrease its efficiency or specified performance, or that allow for an alternative system of comparable cost,
efficiency, and energy conservation benefits.
(c) (1) A solar energy system shall meet applicable health and safety standards and requirements imposed by state and local
permitting authorities, consistent with Section 65850.5 of the Government Code.
(2) Solar energy systems used for heating water in single family residences and solar collectors used for heating water in
commercial or swimming pool applications shall be certified by an accredited listing agency as defined in the Plumbing and
Mechanical Codes.
(3) A solar energy system for producing electricity shall also meet all applicable safety and performance standards established by
the California Electrical Code, the Institute of Electrical and Electronics Engineers, and accredited testing laboratories su ch as
Underwriters Laboratories and, where applicable, rules of the Public Utilities Commission regarding safety and reliability.
(d) For the purposes of this section:
(1) (A) For solar domestic water heating systems or solar swimming pool heating systems that comply with state and federal law,
“significantly” means an amount exceeding 10 percent of the cost of the system, but in no case more than one thousand dollars
($1,000), or decreasing the efficiency of the solar energy system by an amount exceeding 10 percent, as originally specified and
proposed.
(B) For photovoltaic systems that comply with state and federal law, “significantly” means an amount not to exceed one thousand
dollars ($1,000) over the system cost as originally specified and proposed, or a decrease in system efficiency of an amount
exceeding 10 percent as originally specified and proposed.
(2) “Solar energy system” has the same meaning as defined in paragraphs (1) and (2) of subdivision (a) of Section 801.5.
(e) (1) Whenever approval is required for the installation or use of a solar energy system, the application for approval shall be
processed and approved by the appropriate approving entity in the same manner as an application for approval of an architectu ral
modification to the property, and shall not be willfully avoided or dela yed.
(2) For an approving entity that is an association, as defined in Section 4080 or 6528, and that is not a public entity, both of the
following shall apply:
(A) The approval or denial of an application shall be in writing.
(B) If an application is not denied in writing within 45 days from the date of receipt of the application, the application shall be
deemed approved, unless that delay is the result of a reasonable request for additional information.
(f) Any entity, other than a public entity, that willfully violates this section shall be liable to the applicant or other party for actual
damages occasioned thereby, and shall pay a civil penalty to the applicant or other party in an amount not to exceed one thou sand
dollars ($1,000).
(g) In any action to enforce compliance with this section, the prevailing party shall be awarded reasonable attorney’s fees.
(h) (1) A public entity that fails to comply with this section may not receive funds from a state -sponsored grant or loan program
for solar energy. A public entity shall certify its compliance with the requirements of this section when applying for funds from a
state-sponsored grant or loan program.
(2) A local public entity may not exempt residents in its jurisdiction from the requirements of this section.
SEC. 3.
Section 65850.5 of the Government Code is amended to read:
65850.5.
(a) The implementation of consistent statewide standards to achieve the timely and cost-effective installation of solar energy
systems is not a municipal affair, as that term is used in Section 5 of Article XI of the California Constitution, but is instead a
matter of statewide concern. It is the intent of the Legislature that local agencies not adopt ordinances that create unreaso nable
barriers to the installation of solar energy systems, including, but not limited to, design review for aesthetic purposes, and not
unreasonably restrict the ability of homeowners and agricultural and business concerns to install solar energy systems. It is the
policy of the state to promote and encourage the use of solar energy systems and to limit obstacles to their use. It is the intent of
the Legislature that local agencies comply not only with the language of this section, but also the legislative intent to enc ourage
the installation of solar energy systems by removing obstacles to, and minimizing costs of, permitting for such systems.
(b) A city or county shall administratively approve applications to install solar energy systems through the issuance of a building
permit or similar nondiscretionary permit. Review of the application to install a solar energy system shall be limited to the
building official’s review of whether it meets all health and safety requirements of local, state, and federal law. The requi rements
of local law shall be limited to those standards and regulations necessary to ensure that the solar energy system will not have a
specific, adverse impact upon the public health or safety. However, if the building official of the city or county makes a fi nding,
based on substantial evidence, that the solar energy system could have a specific, adverse impact upon the public health and
safety, the city or county may require the applicant to apply for a use permit.
(c) A city, county, or city and county may not deny an application for a use permit to install a solar energy system unless it makes
written findings based upon substantial evidence in the record that the proposed installation would have a specific, adverse
impact upon the public health or safety, and there is no feasible method to satisfactorily mitigate or avoid the specific, adverse
impact. The findings shall include the basis for the rejection of potential feasible alternatives of preventing the adverse i mpact.
(d) The decision of the building official pursuant to subdivisions (b) and (c) may be appealed to the planning commission of the
city, county, or city and county.
(e) Any conditions imposed on an application to install a solar energy system shall be designed to mitigate the specific, adverse
impact upon the public health and safety at the lowest cost possible.
(f) (1) A solar energy system shall meet applicable health and safety standards and requirements imposed by state and local
permitting authorities.
(2) Solar energy systems for heating water in single family residences and solar collectors used for heating water in commercial
or swimming pool applications shall be certified by an accredited listing agency as defined in the California Plumbing and
Mechanical Codes.
(3) A solar energy system for producing electricity shall meet all applicable safety and performance standards established by the
California Electrical Code, the Institute of Electrical and Electronics Engineers, and accredited testing laboratories such a s
Underwriters Laboratories and, where applicable, rules of the Public Utilities Commission regarding safety and reliability.
(g) (1) On or before September 30, 2015, every city, county, or city and county, in consultation with the local fire department or
district and the utility director, if the city, county, or city and county operates a utility, shall adopt an ordinance, consistent with
the goals and intent of subdivision (a), that creates an expedited, streamlined permitting process for small residential rooftop solar
energy systems. In developing an expedited permitting process, the city, county, or city and county shall adopt a checklist of all
requirements with which small rooftop solar energy systems shall comply to be eligible for expedited review. An application that
satisfies the information requirements in the checklist, as determined by the city, county, and city and county, shall be deemed
complete. Upon confirmation by the city, county, or city and county of the application and supporting documents being complet e
and meeting the requirements of the checklist, and consistent with the ordinance, a city, county, or city and county shall,
consistent with subdivision (b), approve the application and issue all required permits or authorizations. Upon receipt of an
incomplete application, a city, county, or city and county shall issue a written correction notice detailing all deficiencies in the
application and any additional information required to be eligible for expedited permit issuance.
(2) The checklist and required permitting documentation shall be published on a publically accessible Internet Web site, if the
city, county, or city and county has an Internet Web site, and the city, county, or city and county shall allow for electroni c
submittal of a permit application and associated documentation, and shall authorize the electronic signature on all forms,
applications, and other documentation in lieu of a wet signature by an applicant. In developing the ordinance, the city, coun ty, or
city and county shall substantially conform its expedited, streamlined permitting process with the recommendations for expedite d
permitting, including the checklists and standard plans contained in the most current version of the California Solar Permitt ing
Guidebook and adopted by the Governor’s Office of Planning and Research. A city, county, or city and county may adopt an
ordinance that modifies the checklists and standards found in the guidebook due to unique climactic, geological, seismologica l, or
topographical conditions. If a city, county, or city and county determines that it is unable to authorize the acceptance of an
electronic signature on all forms, applications, and other documents in lieu of a wet signature by an applicant, the city, co unty, or
city and county shall state, in the ordinance required under this subdivision, the reasons for its inability to accept electr onic
signatures and acceptance of an electronic signature shall not be required.
(h) For a small residential rooftop solar energy system eligible for expedited review, only one inspection shall be required, which
shall be done in a timely manner and may include a consolidated inspection, except that a separate fire safety inspection may be
performed in a city, county, or city and county that does not have an agreement with a local fire authority to conduct a fire safety
inspection on behalf of the fire authority. If a small residential rooftop solar energy system fails inspection, a subsequent
inspection is authorized, however the subsequent inspection need not conform to the requirements of this subdivision.
(i) A city, county, or city and county shall not condition approval for any solar energy system permit on the approval of a solar
energy system by an association, as that term is defined in Section 4080 of the Civil Code.
(j) The following definitions apply to this section:
(1) “A feasible method to satisfactorily mitigate or avoid the specific, adverse impact” includes, but is not limited to, any cos t-
effective method, condition, or mitigation imposed by a city, county, or city and county on another similarly situated application
in a prior successful application for a permit. A city, county, or city and county shall use its best efforts to ensure that the selected
method, condition, or mitigation meets the conditions of subparagraphs (A) and (B) of paragraph (1) of subdivision (d) of Section
714 of the Civil Code.
(2) “Electronic submittal” means the utilization of one or more of the following:
(A) Email.
(B) The Internet.
(C) Facsimile.
(3) “Small residential rooftop solar energy system” means all of the following:
(A) A solar energy system that is no larger than 10 kilowatts alternating current nameplate rating or 30 kilowatts thermal.
(B) A solar energy system that conforms to all applicable state fire, structural, electrical, and other building codes as adopted or
amended by the city, county, or city and county and paragraph (3) of subdivision (c) of Section 714 of the Civil Code.
(C) A solar energy system that is installed on a single or duplex family dwelling.
(D) A solar panel or module array that does not exceed the maximum legal building height as defined by the authority having
jurisdiction.
(4) “Solar energy system” has the same meaning set forth in paragraphs (1) and (2) o f subdivision (a) of Section 801.5 of the
Civil Code.
(5) “Specific, adverse impact” means a significant, quantifiable, direct, and unavoidable impact, based on objective, identified,
and written public health or safety standards, policies, or conditions as they existed on the date the application was deemed
complete.
SEC. 4.
No reimbursement is required by this act pursuant to Section 6 of Article XIII B of the California Constitution because a local
agency or school district has the authority to levy service charges, fees, or assessments sufficient to pay for the program or level
of service mandated by this act, within the meaning of Section 17556 of the Government Code.
Solar and Rain Barrel Permit
Streamlining Ordinance
February 3, 2015
Review of an Ordinance to provide an expedited, streamlined
permitting process for small residential rooftop solar systems
for single family dwellings and duplexes and to exempt certain
rainwater catchment systems from permits, with a categorical
exception from CEQA
1
Recommendation:
2
Introduce an Ordinance (2015 Series) amending
Title 15 of the Municipal Code to adopt the
California Solar Permitting Guidebook, provide
for the exception from permits for rain water
catchment systems, and determine that the
project is exempt from the California
Environmental Quality Act pursuant to Section
15061 (b) (3).
Components of Ordinance:
3
To adopt a “streamlining process” for the review
and approval of Solar Photovoltaic permits for
single family dwellings and duplexes.
To exempt certain “water catchment systems”
from requiring a plumbing permit.
First component:
Solar Photovoltaic Applications
As mandated by State regulation under Assembly Bill
2188 an ordinance adopting a streamlining process is
to be adopted on or before September 30, 2015.
The adoption of the “California Solar Permitting
Guidebook” as part of the ordinance will allow simple
prescribed steps whereby an applicant can provide
information and plans for an streamlined review
process.
4
Streamlined Permitting
Process
Streamlining process will allow for the review and
issuance of “small solar photovoltaic roof mounted
systems for single family dwellings and duplexes.
Small system is one that is 10 kilowatts or less.
The intent of the process is for Building & Safety staff to
review and approve the plans and issuance of the
permit as an “over the counter” provided the prescribed
approach as outlined in the “guide book” is met.
Those applications not meeting the prescribed
approach will require a submittal that will be processed
between 1 to three days.
5
The California Solar
Permitting Guidebook
This “permitting guidebook” provides information
and tools in the way of checklists and basic
standard plans for the review.
Tool Kit included in guidebook:
1.Submittal requirements
2.Eligibility checklist for expedited review
3.Solar PV Standard Plans, two options
provided.
4.Structural criteria.
5.MOU regarding plan review and inspections.
6
Second component:
Rain water catchment systems
7
Plumbing Code amendment
This section in the current adopted California
Plumbing Code was amended per City of SLO 2013
Construction & Fire Codes to require permits for
systems that are more than 250 gallons.
To amend Section 15.04 of the San Luis Obispo
Municipal Code to allow for an exception from a
plumbing permit for systems that are no more than
600 gallons.
Most systems are between 500 to 600 gallons
8
Incentives
There are State and other agencies programs that
provide monetary “incentives” in the way of small
grants towards the installation of these system.
The fees levied on these type of permits sometimes
can be one half or more of the incentive making the
project not attractive to the applicant.
Amendment will provide an exception from permitting
for these systems and thus all the monetary
incentives will go directly to the system and not for
permit processing.
9
Recommendation:
10
Introduce an Ordinance (2015 Series) amending
Title 15 of the Municipal Code to adopt the
California Solar Permitting Guidebook, provide
for the exception from permits for rain water
catchment systems, and determine that the
project is exempt from the California
Environmental Quality Act pursuant to Section
15061 (b) (3).
THENewspaper of the Central Coast
TRIBUNE
3825 South Higuera • Post Office Box 112 • San Luis Obispo, California 93406 -0112 • (805) 781 -7800
In The Superior Court of The State of California
In and for the County of San Luis Obispo
AFFIDAVIT OF PUBLICATION
_
AD # 1556786
CITY OF SAN LUIS OBISPO
ORDINANCE NO. 1612 (2015 Series)
OFFICE OF THE CITY CLERK
AN ORDINANCE OF THE CITY COUNCIL
OF THE CITY OF SAN LUIS OBISPO,
CALIFORNIA, AMENDING TITLE 15 OF
THE MUNICIPAL CODE BY ADDING
CHAPTER 15.14 TO PROVIDE AN EXPE-
DITED, STREAMLINED PERMITTING
PROCESS FOR SMALL RESIDENTIAL
ys
ROOFTOP SOLAR SYSTEMS; AMEND -
County of San Luis Obispo
ING TITLE 15 OF THE MUNICIPAL CODE
BY AMENDING CHAPTER 15.04 TO EX-
EMPT CERTAIN RAINWATER CATCH.
MENT SYSTEMS FROM PERMITS
I am a citizen of the United States and a resident of the
County aforesaid; I am over the age of eighteen and not
NOTICE IS HEREBY GIVEN that the City
CcunclI of the City of San Luis Obispo, Cali -
interested in the above entitled matter I am now, and at
> >
fornle, at Its Regular Meeting of February '
3. 2015, introduced the above titled ordf•
all times embraced in the publication herein mentioned
nance upon a motion by Council Member
was, the principal clerk of the printers and publishers of
Rivoirs, second by Vice Mayor Ashbaugh,
and on the following roll call vote:
THE TRIBUNE, a newspaper of general Circulation,
AYES: Council Members Carpenter, Christi•
printed and published daily at the City of San Luis
anson and Rivotre, Vice Mayor Ashbaugh
Obispo in the above named county and state; that notice
and Mayor Marx
at which the annexed clippings is a true copy, was
NOES, None
published in the above -named newspaper and not in any
inplloQ mNo�1G15 Series) - This is
t]r¢ 21991
supplement thereof — on the following dates to wit;
�
a City amending Municipal
Cade Title 15 (Building and Consiructian
FEBRUARY 11, 2015 that said newspaper was duly
Regulations) to provide an expedited,
and regularly ascertained and established a newspaper of
streamlined permitting process for small
residential rooftop solar systems for single
general circulation b Decree entered in the Superior
g Y p
family dwellings and duplexes and to ex-
ex-
empt certain rainwater catchment systems
Court of San Luis Obispo County, State of California, on
from permits, with a categorical exemption
June 9, 1952, Case #19139 under the Government Code
from
crn the California Environmental Quality
of the State of California.
A full and complete copy of the aforemen-
Iloned Ordinance Is available for Inspection
I certify (or declare) under the penalty of perjury that the
and copy in the City Clark's Office, located
at 990 Palm Street, San Luis Obispo, Call-
foregoing is true corrt,
g g ue a ec
for lla, or you may call (805) 781.7100 for
more information.
NOTICE IS HEREBY FURTHER GIVEN
Y�
that the City Council of the City of San Luis
(Signatmkkf Principal Clerk)
Obispo will consider adopting the store.
mentioned Ordinance at Its Regular Meet -
DATED: FEBRUARY 11, 2015
Ing of February 17, 2015 at 6:00 p.m.,
AD COST: $165.36
which will be held in the Council Chamber,
located at 990 Palm Street, San Luis Obi-
spo, Califomia.
Anthony J. Melia
City Clerk
February 11, 20 15 1551MA